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Home My WebLink About188-126MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-41 DUCK IS UNIT SDI 3-41 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 3-41 50-029-21878-00-00 188-126-0 W SPT 9782 1881260 2446 2175 2124 2163 2132 149 255 252 251 4YRTST P Adam Earl 5/5/2022 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:DUCK IS UNIT SDI 3-41 Inspection Date: Tubing OA Packer Depth 832 2749 2740 2736IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509114300 BBL Pumped:4.5 BBL Returned:4.5 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 14:50:04 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 5 2020 1. Operations Abandon LJ Plug Perforations Li Fracture StimulatlLj Pull Tubing Li AGGGG,-n Performed: Suspend ❑ Perforate ❑ Other Stimulat Aller Casin g ❑ Change Approved Program ❑ Plug for Redrill ❑-rforate New Pool ❑ Repair Wee Re-enter Susp Well ❑ Other: Install Surface Casing Patch Q 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic❑ Exploratory 1:11 Service e 188-126 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21878-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047502 & ADL0047503 DUCK IS UNIT SDI 3-41 I 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A ENDICOTT / ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 13,760 feet Plugs measured N/A feet true vertical 10,517 feet Junk measured N/A feet Effective Depth measured 13,678 feet Packer measured 12,714 feet true vertical 10,459 feet true vertical 9,784 feet Casing Length Size MD TVD Burst Collapse Conductor 92' 30" 131' 131' N/A N/A Surface 2,467' 13-3/8" 2,505' 2,503' 5,020psi 2,260psi Production 10,715' 9-5/8" 10,715' 8,300' 6,870psi 4,760psi Production 2,368' 9-5/8" 13,023' 10,003' 8,150psi 5,090psi Liner 993' 7" 13,760' 10,517' 11,220psi 8,530psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 5-1/2" 17# / L-80 / NSCT 12724 9,792' Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / 12,848' 9,881' 9-5/8" x 5-1/2" 12,714 MD 1,564 MD Packers and SSSV (type, measured and true vertical depth) TIW HBBP 5-1/2" OTIS SVLN 9,784 TVD 1,564 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 24,102 700 2,246 Subsequent to operation: 0 0 22,860 550 2,256 14. Attachments (required ver 20 AAC 25.070, 25.071. a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development ❑ Service ❑� Stratigmphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑' WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-573 ` Authorized Name: Chad Helgeson Contact Name: David Gorm Authorized Title: Operations Manager Contact Email: dclorm(o7.hilcoro.com Authorized Signature: Date: 2/24/2020 Contact Phone: 777-8333 Form 10-404 Revised 4/2017 iBDMS rw FEB 2 0 2020 zO Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-41 N/A 50-029-21878-00-00 188-126 1/1/2020 2/2/2020 1/1/2020 - Wednesday PT PCE TO 250psi LOW, 4,800 HIGH. Brush & Flush TBG WHILE LRS PUMPS 290bbls OF SEAWATER, FOLLOWED BY 70bbls OF DIESEL FRZ PRT (tools setting down @ 12,668' slm, but able to work past. Possibly the TIW Overshot). BRUSHED THE XN NIPPLE @ 12,806' MD. 1/2/2020 - Thursday PT PCE TO 250psi LOW, 4,800 HIGH. SET 4-1/2" PXN PLUG BODY IN XN-NIP @ 12,776' SUM / 12,806' MD (oal-25", w/ 4x3/16" eq ports). ATTEMPT TO SET 96" P -PRONG IN PLUG BODY BUT CAN'T WORK 3.60" BELL GUIDE PAST TIW OVERSHOT @ 12,662' SLM (12,695' MD) - Lost the prong in the overshot area. RAN KJ, 3.75" CENT & 2-1/2" JDS. SET DOWN IN OVERSHOT AREA BUT ABLE TO WORK PAST, SO CHASED PRONG DOWN TO PLUG BODY. APPEARED TO LATCH UP SO JARRED ON TO SHEAR PULLING TOOL. JARRED ON FOR AN HOUR BUT APPEARS TO BE STILL LATCHED UP. POOH & TOOLS INDICATE WE GOT BESIDE THE PRONG. RAN KJ, 3.75" CENT & 2.50 BLING BOX TO P -PRONG @ 12,768' SLM & BLEED TBG PRESSURE FROM 1,600psi TO 450psi, (NO OBVIOUS MARK INDICATING THAT WE WERE SETTING DOWN ON TOP OF THE PRONG - SLIGHT GOUGE ON THE BTM CORNER OF THE BLIND BOX BUT NOT ABLE TO VERIFY THAT IT'S THE PRONG TOP. AFTER INSTALLING THE TREE CAP THE TBG PRESSURE CAME UP TO 1,100psi IN APPROX 20min. 1/3/2020 - Friday PT PCE TO 250psi LOW, 4,800psi HIGH. PULL P -PRONG FROM 4-1/2" PXN PLUG BODY @ 12,768' SLM (packing in great condition). PULL 4-1/2" PXN PLUG BODY FROM XN-NIP @ 12,776' SLM / 12,806' MD (packing in great condition). SET 5-1/2" PX PLUG BODY IN X -NIP @ 12 600' SLM 12,632' MD (oal-30", 4x1/8" eq ports) SET 96" P -PRONG IN PX PLUG BODY @ 12,596' SLM (1-3/4" FN & 1-3/4" body/max o.d.) BLED TBG PRESSURE FROM 1500psi TO 0 si AND MONITOR FOR APPROX. 2 HOURS W/ NO PRESSURE CHANGE. 1/4/2020 -Saturday Washed and prepped cellar to be cut. Cut inspection windowss in conductor at 07:00 and 01:00 positions at 24"for Mistras to inspect. Showing good nominal thickness of 9-5/8. 1/5/2020 -Sunday Cut out cellar floor and begin removing gravel down to 2 ft for additional conductor inspection hole at expected leak depth. 1/6/2020 - Monday Removed gravel down to 2ft below cellar floor for UT inspection hole. 1/7/2020 -Tuesday Removed gravel down 2' from old cellar floor. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-41 N/A 50-029-21878-00-00 188-126 1/1/2020 2/2/2020 1/8/2020- Wednesday Vac'd out OA with 20'x3/8" hose possibly down to leak. Job postponed until patch for casing arrives. 1/9/2020 - Thursday No operations to report. 1/10/2020 - Friday No operations to report. 1/11/2020 -Saturday No operations to report. 1/12/2020 -Sunday Installed slip in shoring pieces and bolted together. Super sucker vac'd out gravel making cellar "'9' deep. 1/13/2020 - Monday Cut windows in conductor centered at 88" below OA com anion valve at 07:00 and 01:00 positions. Mistras inspected casing and found minimal surface corrosion resulting in .347 metal thickness in lowest area. Job okay to carry on without support structure per town engineer. Cleaned out contaminated cement as deep as possible (still contaminated cement below reachable area). 1/14/2020 -Tuesday Rigged up crane to support wellhead. Made vertical cuts from top of landing ring down to windows on conductor using air arc. Released weight from crane for the night and wellhead showed no signs of movement. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number StartDate End Date END 3-41 N/A 50-029-21878-00-00 188-126 1/1/2020 2/2/2020 1/15/2020 - Wednesday Installed Cellar shoring sleeve inside of existing conductor 6' below original cellar floor 1/16/2020 - Thursday Spent the day cutting the 30" conductor in pieces with air arc. Found hard cement. Obtained chisels and a jack hammer to remove cement. 1/17/2020 - Friday RU N2 to pressure test in attempt to locate leak. Began flow of N2 and noticed that we had fluid coming from lower than we cut the conductor. RD N2 set up and prepare to cut lower. 1/18/2020 -Saturday Dug down another 3' in cellar and inside conductor. Hooked up our N2 and began flow. Imediately found hole. 1/19/2020 -Sunday No operations to report. 1/20/2020 - Monday Did a UT grid every 2" to see where good base metal was. Lowest reading was .37". Patch will need to be 7' long. 1/21/2020 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-41 N/A 50-029-21878-00-00 188-126 1/1/2020 2/2/2020 1/22/2020 - Wednesday No operations to report. 1/23/2020 - Thursday 3' shoring extension sleeve in place. Used supersucker to dig down another 3' to give room to weld. Hit water at 1.5' 1/24/2020 - Friday Spread out 30 sacks of bentonite in the hole, along with % yard of gravel for a binder to mitigate the ground water. 1/25/2020 -Saturday Ground water is mitigated and able to continue to cut more conductor off to the proper depth and to start welding bands on. 1/26/2020 -Sunday No operations to report. 1/27/2020 - Monday No operations to report. 1/28/2020 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-41 Slickline 50-029-21878-00-00 188-126 1 12/31/2019 2/2/2020 1/29/2020 - Wednesday K020-Friday ations to report. 20 - Thursday to 1000psi, ***PASSED***. NO signs of fluid in cellar ations to report. 0 -Saturday CONTINUE ON FROM 1-31-20 WSR, WELL S/I ON ARRIVAL. (pull ttp). PT PCE TO 250psi LOW, 2,500psi HIGH . PULLED P - PRONG FROM PX PLUG BODY @ 12,597' SLM . MAKE TWO ATTEMPTS TO PULL 5-1/2" PX PLUG BODY FROM X -NIP @ 12,590' SLM (12,632' MD). JAR FOR APPROX 1 HOUR & 15min, JAR DOWN FOR 15min AFTER SHEARING OFF THE SECOND TIME. 2/2/2020 -Sunday CONTINUE ON FROM 2-1-20 WSR. PT PCE TO 250psi LOW, 2,500psi HIGH. PULLED 5-1/2" PX PLUG BODY FROM X -NIP @ 12,590' SLM (12,632' MD). WELL LEFTS/I ON DEPARTURE, PAD -OP NOTIFIED. 2/3/2020 - Monday No operations to report. 2/4/2020 -Tuesday No operations to report. Endicott 3-41 Casing Repair 12/8/2019 Found surface casing leak. Shut-in well and freeze protected. Installed safe out. 12/12/2019 Purged OA with nitrogen to evacuate fluids. Removed OA companion valve and found leak to be at 88" below OA Valve. Re -installed OA companion valve. 12/30/2019 Pulled Flowline C -spool and GL spool. Removed cellar grating. 1/3/2020 S/L Pulled SSSV and set 5-1/2" PX plug body, Bled TBG, IA, OA to 0# 1/4/2020 Washed and prepped cellar to be cut. Cut windows in conductor at 07:00 and 01:00 positions 1/6/2020 1/7/2020 1/8/2020 Vac'd out OA with 20'x3/8" hose possibly down to leak. Job postponed until patch for casing arrives (possibly 2-3 days out). 1/12/2020 Installed slip in shoring pieces and bolted together. Super sucker vac'd out gravel making cellar "'9' deep. 1/13/2020 Cut windows in conductor centered at 88" below OA companion valve at 07:00 and 01:00 positions. Mistras inspected casing and found minimal surface corrosion resulting in .347 metal thickness in lowest area. Job okay to carry on without support structure per town engineer. Cleaned out contaminated cement as deep as possible (still contaminated cement below reachable area). 1/14/2020 Rigged up crane to support wellhead. Made vertical cuts from top of landing ring down to windows on conductor using air arc. Released weight from crane for the night and wellhead showed no signs of movement. 1/15/20 Installed Cellar shoring sleeve inside of existing conductor 6' below original cellar floor 1/16/20 Spent the day cutting the 30" conductor in pieces with air arc. Found hard cement. Obtained chisels and a jack hammer to remove cement 1/17/20 RU N2 to pressure test in attempt to locate leak. Began flow of N2 and noticed that we had fluid coming from lower than we cut the conductor. 1/18/20 Dug down another 3' in cellar,and inside conductor. Hooked up our N2 and began flow. Imediately found hole. 1/20/20 Did a UT grid every 2" to see where good base metal was. Lowest reading was .37". Patch will need to be 7' long. Will need to dig a little deeper to weld lower band on. 1/23/20 3' shoring extension sleeve in place. Used supersucker to dig down another 3' to give room to weld. Hit water at 1.5' 1/24/20 Spread out 30 sacks of bentonite in the hole, along with % yard of gravel for a binder to mitigate ground water 1/25/20 Ground water is mitigated and able to continue to cut more conductor off to the proper depth and to start welding bands on. 1/26/20 Cleaned up casing, set up scaffold and welded lower band on IA. Wrapped it with blankets for 24hr cool down. 1/27/20 Built scaffold in cellar to reach the top band location. Cleaned up casing and welded top band to IA. Wrapped it with blankets for 24hr cooldown. 1/29/20 Lowered in and aligned sleeve, approved by Mistras, began tacking in place and welding late afternoon. 1/30/20 Weld of sleeve complete. Mistras out inspecting welds now. MIT OA to 1000 PSIG completed successful lost 14, 18, 18, and 16 psi. Well known to have a slight leakoff through shoe. No fluids observed at surface. 2/2/20 Conductor welded in place, along with wellhead & tree stabilizers. THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, SDI 3-41 Permit to Drill Number: 188-126 Sundry Number: 319-573 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the 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, SIassie L. Chmielowski Commissioner DATED this day of December, 2019. ABOSA-1 DEC 19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 28Q rt pg C:kms.a�6.9.11 DEC 17 2019 ors 9%017111AOGCC 1. Type of Request: Abandon El Plug Perforations LJ`vFracture Stimulate ❑ Repair Well ❑� Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Sus p Well ❑ Alter Casing ❑ Other: Install Surface Casing Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 188-126 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 Stratigraphic ❑ Service Q • 6. API Number: Anchorage Alaska 99503 50-029-21878-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No Q DUCK IS UNIT SDI 3-41 ' 9. Property Designation (Lease Number): 1o. Field/Pool(s): hDt c,014 7) L,ZADL0047503 ENDICOTT / ENDICOTT OIL if. 12.t ?, t-1 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): • 13,760' 10,517' 13,678' 10,459' 4,742 N/A N/A Casing Length Size MD ND Burst Collapse Conductor 92 30" 131' 131' N/A N/A Surface 2,467' 13-3/8" 2,505' 2,503' 5,020psi 2,260psi Production 10,715' 9-5/8" 10,715' 8,300' 6,870psi 4,760psi Production 2,368' 9-5/8" 13,023' 10,003' 8,150psi 5,090psi Liner 993' 7" 13,760' 10,517' 11,220psi 8,530psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5-1/2" 17# / L-80 / NSCT 12,724' See Schematic See Schematic 4-1/2" 12.6# / L-80 / 12,848' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): 9-5/8" x 5-1/2" TIW HBBP and 5-1/2" OTIS SVLN 12,714 MD / 9,784' ND and 1,564 MD/ 1,564 ND 12. Attachments: Proposal Summary _Z.j Wellbore schematic r7 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ 14. Estimated Date for 15. Well Status after proposed work: 1/1/2020 OIL ❑ WDSPL Commencing Operations: ❑ ❑ WINJ ❑ Suspended 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard w �' Authorized Title: Operations Manager Contact Email: vvrivardCcDhiIcorp.com Contact Phone: 777-8547 Authorized Signature: Date: 12/17/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ s Other: - M (T — OA 1000103,& 4 Fyvo� �`" ."� `'F T� RBDMS 0JDEC 19 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes L1 No Subsequent Form Required: /(D APPROVED BY Approved by: � d��. COMMISSIONER THE COMMISSION Date: 12, I /z iel � l j Submit Form and Form `t6-403 Revised 4/2077 Approved applicat i Ii a date of approval. Attachments in Duplicate U Iiilc.m Alaska, LD Surface Casing Leak Diagnostics Well: END 3-41 PTD:1881260 API: 50-029-21878-00-00 Well Name: END 3-41 API Number: 50-029-21878-00-00 Current Status: SI Rig: SL Estimated Start Date: 1/1/20 Estimated Duration: 12 Reg.Approval Req'std? No Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1941420 First Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE/PO: PO Current Bottom Hole Pressure: 5,742 psi @ 10,000' TVD Max Bottom Hole Pressure: 5,742 psi @ 10,000' TVD Max. Proposed Surface Pressure: 4,742 psi Recent SI Surface Pressure: 100psi Brief Well Summary: (Based on SBHPS on 9/17/17) (Based on SBHPS on 9/17/17) (Max BHP -(0.1 psi/ft x 10,000 TVD) (Taken on 12/16/19) END3-41 was SI on 12/8/19 following a confirmed hydrocarbon leak from the conductor. In July 2019 the well had a passing MIT -OA to 500 psi then a cement top job was performed bringing cement up from 6 ft below the flutes to 1 ft. The remaining 1ft was then capped with Fill Coat #7 corrosion inhibiting (CI) grease. Prior to the 7/29/19 application, the well had not had Cl placed in the conductor annulus. WHPs during the most recent leak were T/I/O = 2256/159/0. The well previously had a furmanite wrap installed in 2010 to repair a starting head connection leak. Initial diagnostics show the leak is in the surface casing 88" below the OA valve and is not related to the furmanite wrap/starting head leak. Objective: Excavate, remove conductor and weld an external surface casing patch to restore OA integrity. -'� Notes On Wellbore Condition: • The well had a passing MIT -IA to 2,900 psi on 5/31/2019. • Well has a furmanite composite wrap to repair a leak in the starting head connection. Do not MIT -OA above 1,200 psi or place methanol in OA. • Well had a passing MIT -OA to 500 psi on 7/29/2019 prior to a cement and Cl inhibitor top job. • Surface casing leak confirmed while pumping diesel at 365 psi. Leak depressed with N2 and found -88" below the OA valve. • Leak is -4 ft below the conductor landing ring and -2ft below the cellar floor. Full excavation of well cellar will be required reach the leak site. Procedure: Pre -Sundry Work Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 4,800 psi high. 3. RIH and pull 5.5" MCX from 1564' MD 4. MU plug toolstring and set a 4-1/2" XN plug @ 12,806' a. Bleed down the tubing pressure to confirm set. 5. RDMO Prep Work 6. Disconnect flowline and instrumentation. Surface Casing Leak Diagnostics Well: END 3-41 PTD:1881260 Hil.rn Al.ku, LG API: 50-029-21878-00-00 7. Verify tubing, IA and OA pressures have been bled to Opsi. 8. Complete an ACWR (Area Civil Work Request) which includes a locate for all utilities, thermosyphons and all underground infrastructure. Sundry Work (Approval required to proceed) Surface Casing Repair 9. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations 10. Excavate and install shoring to a depth of "'7' below existing cellar floor to provide enough room to access the leak site. Grade out the front for secondary egress. a. Primary plan is to use modular shoring boxes. Hold additional onsite JSA to determine if adjacent wells (END 3-39 & END 3-43) will remain online or be shut in to move the shoring boxes in place. b. All excavations will comply with the ASH handbook and OSHA Regulations. c. A competent person will be onsite during the excavation and perform daily checks prior to entry by personnel. 11. Install high volume water pumps into a low spot in the floor of the excavation as needed. a. Previous casing repairs on END 2-12 and END 1-61 have benefited from placing a sump pump in a hole in front of/adjacent to wellhouse. 12. Deconstruct and remove the existing well cellar. 13. Install secondary containment around lower edge of conductor. 14. Drill (cold cutting drill bit) or cut (air arc) holes in the conductor roughly 3' and 6' below the landing rig to ensure adequate space for surface casing patch. 15. Remove cement as needed and UTthrough inspection holes to confirm weldable, uncorroded surface casing near hole depth before cutting conductor. 16. Flush conductor with water from the landing ring while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 17. Install N2 purge equipment for the conductor and OA a. Use of an N2 cap/purge will be determined on site, prior to proceeding, with accurate gas readings and fluid returns observed. b. Prior to cutting conductor, install continuous gas monitoring for LEL's from the conductor. c. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 18. Cut and remove conductor from above the 6 ft inspection holes. a. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. b. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. Alternately, if there is not sufficient room to drop the landing ring below the patch area, the vertical cut may be carried all the way up and through the landing ring. 19. Chip away excess cement from the surface casing. Buff and prepare surface casing for inspection and welding. 20. Inspection department to UT the exposed surface casing. a. Inspect for any additional holes. b. Areas to patch to be identified marked and inspected on a grid to ensure competency for welds 21. ITall 14.625" ID clamshell patch. a. Nate that there may be a 1-3ft pup joint with collared connection below the starting head that may need to be straddled to weld to good metal above and below leak. b. Circumferentially weld band/spacer rings to the surface casing for the upper and lower patch areas Surface Casing Leak Diagnostic Well: END 3-41 PTD:1881260 Ilawra Alaska, LU API: 50-029-21878-00-00 i. Band material: A572-50, ID=13.375" thickness=.625". c. Install clamshell patch and weld circumferentially to the spacer rings and vertically to the other patch half. iii ov2� S<<an'j, c <• ii. Patch material: A572-50, ID=14.625" thickness=l/2' . 22. Inspect the welds to ensure competency. �- 23. Conduct an MIT -OA to 1,OOOpsi to confirm SC integrity. a. Do not exceed 1,200 psi due to rating of furmanite wrap. 24. Re -install cellar and backfill ground around the conductor and cellar. 25. Re -install flowline and instrumentation. Slickline 26. MIRU SL unit. 27. Pressure test to 300psi low and at least 4800psi high. 28. Use GLpressure 29. RIH andnd pullpull 4 4-1/2" XN plug from 12,80>� V /`f 30. RIH and set 5.5" MCX at 1,564' MD 31. RDMO 32. Turn well back over to production Post Repair Work 33. Weld cut conductor halves back onto conductor. 34. Reinstall well house and backfill gravel over cellar liner. 35. Cement SC by Conductor Annulus back to within 1ft of conductor top. 36. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Attachments: -Wellbore Schematic -SC Leak Location F TREE= aw WELLHEAD= McEvoy ACTUATOR= AXELSON INTIAL KB. E E 55.3' BF. 0- = 16.5' KOP= Wx Angle = L6tumMD= Datum ND= 53" @ 8363' — 1310V 1000055 'F8" CSG, 68#, 12AW END 3 -41 sAFEr'" NDTPS: H2S READINGS AVERAGE 230- 260 PPM ON AIL & GAS INJECTORS """ WELL REQUIRES ASSSV" COMPOSITE WRAP REPAIR SH LEAK -DO NOT f�1MP MED11M EfH BLErD INTO OA DIE TO CHEM INCOMPATIBILITY w 1�XY RESIN IN WRAP O 5-1/2'"CHROMEN9�PL�"* 1554' 5-112"OTS H2O SVLN is_cRln=n5a2^ Minimum ID = 3.725" @ 12806' 4-112" HES XN NIPPLE 5-1/2- TBG, 17#, L-80 NSCT, .0232 bpf, D =4.892" D=3.958' =8.s6r I --I 13023' PERFORATION SUNWRY REF LOG: DLL -GR on 12/31/88 & CBT on 01/05/89 ANGLE AT TOP PERF: 47" @ 13134' Nate: Refer to Production DB for historical perf data SIZE SPF I INTERVAL Opn/Sgz SHOT SOZ 2-7/8 5.5 13134 -13182 O 001407 RK RK 3-318 6 13412 - 13421 O 05/13189 3-3/8 6 113426 - 13442 O 06112/89 3-318 6 13532 - 13624 O 02128193 RAST FTAMNt Pc STI MD I TVD 1DEV VLV LATCH POFir DATE 2 1 4361 12561 4141 48 40 RP DMY RK RK 0 0 01/07/97 08/04/94 9667 'f 72632' �–jSt2"HESXNP(9"CI�,D=4.56: 12695' 9-SB"X5.1/2"TTNOVEZSFIOT 12712' 9.5/8'X5.112" TTN LATCH 12714' 9-5/6" X 5-72" 7111V HBBP R(IZ. D = 12724' 5-712"X4-iP2"XO,D=3.813" 12765' 4-1/2' 0T6 X NP, D=3.$13" 12806' 12RAR' 4-112" OTS XN NP, D = 3.725" 4-712" iM. FC In= a av 7"LNP 29#, NP95HIS, 13760' Hilcorp Alaska LLC .0371 bof. D=6.184" END 3-41 (PTD # 1881260) 12-18-19 CURRENT CONFIGURATION 7 1/16" 5K Cameron FL tree with actuated second master and actuated wing. 133/8x95/8x5 1/2 to bu la rs 13 3/8" 3K x 13 3/ 8" 5K McEvoy Split Speeedhead, 2 seal extended neck. 3 1/8" 5K outs. 13-5/ 13-S/E FIGURE. 1 (3) M WELLHEAD ASSEMBLY.ENDICOTT SKSI_ 13-3/p"x 9-S/p•'x 4-1/2" Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, December 9, 2019 9:28 AM To: Wallace, Chris D (CED) Cc: Schwartz, Guy L (CED); Regg, James B (CED); Alaska NS - Endicott - Operations Leads; Alaska NS - Endicott - Field Foreman; Chad Helgeson Subject: Endicott Injector SDI 3-41 (PTD #1881260) Hydrocarbons in Conductor Annulus Attachments: END 3-41 TIO.XLSX All, Endicott water injector 3-41(PTD #1881260) was observed on 12/8/19 to have hydrocarbons at the top of the surface casing by conductor annulus with T/1/0=2256/650/159. The well was shut-in and will remain shut-in until integrity can be restored. The well previously had a furmanite composite wrap repair in 2010 for a starting head leak however initial indications are that the current leak is below the starting head and likely a surface casing leak. An MIT -OA was attempted but returns to the conductor were observed with OA at 365 psi. Once shut-in, the OA was bled down and bubbling in the conductor stopped. A TIO plot is attached for reference. Path Forward —Operations (1) Obtain an initial OA fluid level shot following well shut-in. (2) Depress OA fluid level with N2 bottles and determine SC leak depth. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0hilcorn com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this e-mail message is confidential information intended only for the use of the recipient($) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1A I Hilcorp Alaska, LLC August 26, 2019 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue, Suite 100 Anchorage, Alaska 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8547 t,—,€"c� rr cr . P.. t AUG 2 g 20 Re: Endicott Conductor Annulus Cement and Corrosion Inhibitor Treatments 8/6/19-8/18/19 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of Endicott wells that were treated with cement and corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease -like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, API and PTD numbers, treatment dates and volumes. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, (�w Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC Endicott Surface Casing by Conductor Annulus Cement Top Job and Fill Coat Corrosion Inhibitor (CI) Applications Well Field API PTD Initial Top of Cement Volume of Cement Pumped (bbis) Final Top of Cement (ft.) Cement Pump Date Corrosion Inhibitor Fill Volume (gal) Final Cl Top (ft.) Corrosion Inhibitor Treatment Date 1-61 DIU 50029225200000 1941420 6.5 3.86 1 8/6/2019 23 Flush w/top of conductor 8/18/2019 2-12 DIU 50029223020000 1921170 SS 10.18 0.5 8/6/2019 IB Flush w/top of conductor 8/18/2019 3-11 DIU 50029218480000 1880870 9.2 6.11 0.5 8/9/2019 7 Flush w/top of flutes 8/18/2019 3-25B DIU 50029221250200 2030210 12.2 7.87 1 8/9/2019 3 Flush w/top of flutes 8/18/2019 3-41 DIU 50029218780000 1881260 6.4 3.79 1 8/10/2019 5 Flush w/top offlutes 8/18/2019 3-45 DIU 50029218110000 1880510 5.2 2.95 1 8/9/2019 5 Flush w/top of flutes 8/18/2019 3-47 DIU 50029215690000 1860640 2.9 1.33 1 8/9/2019 3 Flush w/top offlutes 8/18/2019 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg r2 DATE: Friday,June 01,2018 1 P.I.Supervisor '\ i 61L(l SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-41 FROM: Austin McLeod DUCK IS UNIT SDI 3-41 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-41 API Well Number 50-029-21878-00-00 Inspector Name: Austin McLeod Permit Number: 188-126-0 Inspection Date: 5/31/2018 Insp Num: mitSAM180531205350 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min �I --- 538 2975 l 2092 2098 2968 ' 2967 ' Well � 3-41 "Type? Inj W TTVD 9782 Tubing� 2089 20 56 � PTD 1881260 Type Test; SPT Test psi 2446 BBL Pumped: 4.7 BBL Returned: 4.4 OA 180 • 210 210 210 • Interval 4YRTST P/F' P ,/ Notes: MIT-IA.2975 psi to achieve 500+differential of adjacent annulus � it same JUN 0 b201 Friday,June Ol 2018 � Page 1 of 1 • • RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 JUHilcorpAlaska,LLC L 3 0 201'i 3800 Centerpoint Drive Suite 100 A0GccAnchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission + S S 333 West 7th Avenue, Suite 100 Anchorage, AK 995013 5 EP O ( a D l b SG��NEP Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/134" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp I _ New API WeIINo 1 PermitNumberl WellName I WeIlNumber I WeIlNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/139 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/137 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/140 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/030 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/530 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 Ima~roject Well History File Cover~je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct ins pection of the file. / t~- /~_ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Otb er, No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: .~ OVERSIZED (Non-Scannable) [] Other: , [] Logs of various kinds NOTES: ' ~'Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: IS~ Scanning Preparation BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning Stage, PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: Stage 2 BY~ BEVERLY BREN VINCENT SHERYL MAR A LOWELL DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN IND~VIOUAL PAGE BASIS DUE TO QUALi~'Y, GRAYSCALE OR COLOR IMAGES) Is~ RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked {done) 10/25/02Rev3 NOTScan ned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ¡C?r /rJ /~ FILE # #~ , I 1M! /lI4( To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ,333 W. 7th Ave., Ste. 100 · Anchorage, Alaska 99501 Voice (907) 279-1433 ¡Fax (907) 276-7542 • MU c/K- 3q pJ> s f€g(rz c Regg, James B (DOA) From: Regg, James B (DOA) Sent: Saturday, October 12, 2013 11:06 AM 1 �f 1 1O1(4 (13 To: AK, OPS FF Well Ops Comp Rep Cc: Redmond, Randy; AK, RES END Production Optimization Engineer; AK, D&C Wells Slickline Coordinator; AK, D&C Wireline Operations Team Lead Subject: RE: Endicott 3-41 injection extension Granted ED Sent from Samsung iWhile. Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep cz bp.com> Date: 10/11/2013 6:08 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(2 alaska.gov> Cc: "Redmond, Randy" <RedmonRF @BP.com>,"AK, OPS FF Well Ops Comp Rep" <AKOPSFFWel1OpsCompRep a,bp.com>,"AK, RES END Production Optimization Engineer" <AKRESENDProductionOptimizationEngineer a bp.com>,"AK, D&C Wells Slickline Coordinator" <AKDCWeIlsSlicklineCoordinator(2 p.com>,"AK, D&C Wireline Operations Team Lead" <AKDCWirelineOperationsTeamLead@BP.com> Subject: Endicott 3-41 injection extension Mr. Regg, We have reached the 14 day limit to inject into Endicott water injector 3-41 without a SSSV installed. The well is currently shut in and we seek your approval to return the well to injection. We request a seven day extension to the "14 day rule" to allow for injection stabilization and completion of a slickline (PROF (injection profile) prior to.resetting the SSSV. A little well history on this well: The SSSV was pulled 9/27 to prep for a CTU cleanout. The well was periodically flowed to assist in the CTU cleanout and due to scheduling issues the SL unit was not able to make it to Endicott prior to the 14 days limit being reached. Please advise if we can proceed with this request for the 7 day extension. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) 1 • STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMAIION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LI Underream/FCO Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 188-126-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service El,6.API Number: Anchorage,AK 99519-6612 50-029-21878-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047503 EPA 3-41/K-39 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted ENDICOTT,ENDICOTT OIL • 11.Present Well Condition Summary: Total Depth measured 13760 feet' Plugs measured None feet true vertical 10514.34 feet Junk measured None feet Effective Depth measured 13678 feet Packer measured 12714 feet true vertical 10455.98 feet true vertical 9782.29 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 92 20"x 30" 39-131 39-131 0 0 Surface 2467 13-3/8"68#L-80 38-2505 38-2503.03 5020 2260 Intermediate None None None None None None Production 12986 9-5/8"47#NT95HS 37-13023 37-10000 8150 5080 Liner 1003 7"29#NT95HS 12757-13760 9813.75-10514.34 9690 7820 Perforation depth Measured depth 13134-13154 feet 13154-13162 feet 13162-13182 feet 13412-13421 feet 13426-13442 feet 13532-13534 feet 13534-13624 feet True Vertical depth 10075.26-10089.0;feet 10089.02-10094.5!feet 10094.55-10108.45 feet 10269.21-10275.4 feet 10278.86-10289.81 feet 10352.34-10353.7 feet 10353.75-10417.5!feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 4-1/2"TIW HBBP Packer 12714 9782.29 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13134'-13624' SCANNED NOV Treatment descriptions including volumes used and final pressure: SCANNED NO 0 6 2013 682 BBL 3%NH4CI,71 BBL 12%HCL(11.8%TITRATED),68 BBL 9:1 MUD ACID(9.7%HCI/12%HF TITRATED) 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPLU GSTOR ❑ WINJ 12 , WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(p„BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician f.'► il W , S'.•: . ~'..."-/w.J• VAA/,a■moni► / Phone 564-4035 Date 6/25/2013 ivies4110%;/✓ice///�!I/ %iv- V/' F RBDMS JUL - 2 201 /3/ / 13 Form 10-404 Revised 10/2012 r \7C ' (�J ' Submit Original Only • • Daily Report of Well Operations ADL0047503 T/I/0=617/4/169, Temp=S/I, Schmoo-B-Gone Treatment(Fill Clean out and Aci stim) Pumped 5 bbls meth followed by 297 bbls SBG mix and 5 bbls meth to freeze 5/17/2013 protect tree. Allow 3 hr soak. Job continued on 5-18-13 WSR Job continued from 5-17-13 WSR Pumped 297 bbls of 1% KCL rinse followed by 15 bbls meth to freeze protect tree. Well tender notified of well condition upon departure. 5/18/2013 FWHP's=1375/3/47 SV,WV,SSV=closed, MV=open, IA and OA=OTG ***WELTS/1 ON ARRIVAL***(pre-coil-fco) R/U SLICKLINE UNIT 4515 & PT 5/27/2013 ***CONT. ON 5/28/13 WSR*** ***CONT. FROM 5/27/13 WSR***(pre-coil-fco) TAG MCX @ 1,533' SLM (1,584' MD) PULL 5-1/2" MCX FROM 1,533' SLM (1,584' MD) (ser.# NM-504) LOCATED TTL© 12,822' SLM(+26' CORR. TO 12,848' MD) TAGGED HARD BOTTOM @ 13,347' MD=277' FILL RAN PDS 40 ARM CALIPER FROM 13,300' SLM TO SURFACE. 5/28/2013 ***WELL S/I ON DEPARTURE, WELLTENDER NOTIFIED OF STATUS*** CTU#3- 1.75" Coil (CTV= 30.6 bbls) Job Objective: Underreaming, FCO, &Acid Wash Standby for wind speed to cross Sag river bridge. MIRU CTU and make up Underreaming with 2 7/8" motor and Reeve underreamer set for 6.0" OD. RIH. 6/2/2013 ...Job Continued on WSR 6-3-13... CTU#3 - 1.75" Coil ***Continued from WSR 6-2-13*** Job Objective: Underream,Acidize RIH with Underreamer to 13516 and tag softly. PUH and begin underreaming from 13300 down. Taking 25' bites with 10 bbl gel sweeps. Uderreamed to 13,657' and pumped 22-bbls gel pill for bottoms up. PUH to tbg tail, dropped 3/4" ball to activate circ sub. Ball sheared at 3,960 psi. POOH and lay down tools. Ball recovered. MU PDS logging tools and RIH. Tag solid obstruction at 12723' corrected depth. Unsuccessful to jet and pump past. POOH to correct depth using log, add stingers for length, and pick up more rounded nozzle. 6/3/2013 ...Continued on WSR 6-4-13... CTU#3- 1.75" Coil ***Continued from WSR 6-3-13*** Job Objective: Underream and FCO,Acidize RIH with logging BHA and tag bottom at 13, 643 CTM and log from 13,633 to 12,500 @ 50 fpm. Yellow flag painted at 13, 387'. POOH. MU treating packer BHA with spotting valve.Bullhead —470-bbls NH4CI down the backside. RIH and correct depth at flag: 13,413.62' (E), 13,406' (M). Reach pkr setting depth and launch 1/2" ball. Initial shear at—500 psi to fill and expand pkr. Ball sheared at—4,000 psi fully expanding pkr. Perform mini-injectivity test at lower perfs. Open spotting valve and pump pre-flush 30- bbls NH4CI+F103. Close valve and pump 71 bbls of 11.8% HCI and 68 bbl of 9:1 (9.7%, 1.2%) HF followed by 200bbl NH4CI+F103 over displacement. FP coil and equalize and unlatch packer. WHP dropping to —20 psi after equalization. POOH. 6/4/2013 ...Continued on WSR 6-5-13... • • Daily Report of Well Operations ADL0047503 CTU#3-1.75' Coil ***Continued from WSR 6-4-13*** Job Objective: Underream and Acidize POOH and FP well with 40 bbls 50/50 Methanol. Lay down tools and RDMO to J-20. ***Job Complete*** 6/5/2013 FLUIDS PUMPED BBLS 25 METH 297 SCHMOO-B-GONE 1660 1% KCL 1 DIESEL 117 1% SLICK KCL 155 50/50 METH 112 GEL 682 3%NH4CI 71 12% HCL (11.8% TITRATED) 68 9:1 MUD ACID (9.7%HCI/ 12% HF TITRATED) 3188 TOTAL Casing / Tubing Attachment ADL0047503 Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 20"x 30" 39 - 131 39 - 131 LINER 1003 7"29# NT95HS 12757 - 13760 9813.75 - 10514.3 9690 7820 PRODUCTION 12986 9-5/8"47# NT95HS 37 - 13023 37 - 10000 8150 5080 SURFACE 2467 13-3/8"68# L-80 38 - 2505 38 - 2503.03 5020 2260 TUBING 12677 5-1/2" 17#L-80 37 - 12714 37 - 9782.29 7740 6280 TUBING 134 4-1/2" 12.6#L-80 12714 - 12848 9782.29 - 9879.03 8430 7500 • • TREE= aw NO /US S READINGS AVERAGE 230-260 WELLHEAD= MCEVOY END 3-41 PP AIL&GAS INJECTORS***WELL REQUIRES ACTUATOR= AXEL.SON A SSW*"COMPOSITE WRAP REPAIR SH LEAK-DO NuAL KB.fl.E 55.3' I NOT PUMP METH/METH BLEND INTO OA DUE TO BF.ELEV= .__._._ 16.5' CHBN INCOMPATIBIUTY w/EPDXY REIN IN WRAP"* KOP= \ 5-112"CHROME NIPPLES' Max Angle= 53°@ 8383' \` Datum MD= 13105' 1564' 5-112"HRQ SV LN(9-CR),D=4.562" DatumTVD= 10000 SS 13-3/8"CSG,68#,L-80 BTRS, H 2505' , D=12.415" GAS LFT MANDRELS ST ND P10 DEV VLV LATCH PORT DATE 2 4361 4141 48 RP RK 0 01/07/97 1 12561 9667 40 ()MY RK 0 08/04/94 Minimum ID =3.725" {a? 12806' 4-1/2" HES XN NIPPLE 12632' —15-1/2"1-ES X NP(9-CR),ID=4.562" 5-1/2"TBG,17#,L-80 NSCT, --� 12695' 12695' —19-5/8"X 5-1/2"TIW OVERSHOT .0232 bpf,ID=4.892" 12712' —1 9-5/8"X 5-1/2"11W LATCH 12714' —19-5/8"X 5-1/2"71W t-138P FKR,D=4.75" , 12724' —15-10 X 4-1/2"XO,D=3.813" 12765' —I4-1/2"OTIS X NP,ID=3.813" 12806' H4-112"OTIS XN NP,ID=3.725" TOP OF 7"LNR — 1276T 4-1/T TBG,12.6#,I 80, H 12848' 12848' —14112"WLEG,D=3.958" .0152 bpf,D=3.958" 9-5/8"CSG,47#,NT95HS NSCC,D=8.681" --� 13023' PERFORATION SUMMARY REF LOG:DLL-GR on 12/31/88&CST on 01/05/89 ANGLE AT TOP FEW: 47"@ 13134' Note:Refer to Production DB for historical pert data SIZE SPF MsITEFNAL Opn/Sqz SHOT SQZ 2-7/8 5.5 13134-13182 0 07/14/07 v 3-3/8 6 13412-13421 0 06/13/89 3-3/8 6 13426-13442 0 06/12/89 "3-3/8 6 13532-13624 0 02/28/93 • 13459' H 7"MARKER JOINT PsTD H 13678' 11.1.1.11.1.1• 11111111111111111 7"LNR,29#,NT95HS, --� 13760' ►.1.1.1.1.1.1.1.1. .0371 bpf,D=6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT t.NT 02/09/89 JLH ORIG COMPLETION 06/12/13 JTG/JM3 PULLED 5-1/2"WRP(05/05/13) WELL 3-41/K-39 08/06/94 RWO 06/12/13 CF/JM3 DRAWING CORRECTIONS(06/04/1 PERMIT No: '1881260 07/19/07 JM=/PJC PETS(07/14/07) API No: 50-029-21878-00-00 12/28/10 A W/ii/D FORMAT REVISION SEC 8,T11 N,R17E,2504'FN-&650'FEL 04/04/13 DJS/JND SET WRBPIWBS CLEAN UP(03/21/13) 04/25/13 PJC GLV CORRECTION(01/07/971 BP Exploration(Alaska) • • • gw�� \l i 7, : tv THE STATE Alaska Oil and Gas r ®f1�1L1`''1S Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 f i 22 1 03, Fax: 907.276.7542 NEB Steven Cinelli Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, SDI 3-41/K-39 Sundry Number: 312 -429 Dear Mr. Cinelli: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .994,44-- Cathy P Foerster Chair DATED this of of November, 2012. Encl. , • • 4SL A I IIECEIVED OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 0 82012 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGGC 1. Type of Request: Abandon ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ 9 , Operations Shutdown ❑ Re -enter Susp. WeII❑ AUD Stimulate 0 • Alter Casing ❑ Other c TU co 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. 11 /j3 //Z BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 188 -126-0 ' VLr 3. Address: Stratigraphic ❑ Service 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50-029 -21878 -00-00 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? SDI 3- 41/K -39 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0047503 • ENDICOTT, ENDICOTT OIL • 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): 13760 . 10514 13678 10456 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 92 20" x 30" 39 - 131 39 -131 Surface 2467 13 -3/8" 68# L -80 38 - 2505 38 - 2503.03 5020 2260 Intermediate None None None None None None Production 12986 9 -5/8" 47# NT95HS 37 - 13023 37 -10000 8150 5080 Liner 1003 7" 29# NT95HS 12757 - 13760 9813.75 - 10514.34 9690 7820 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4 -1/2" TIW HBBP Packer Packers and SSSV MD (ft) and TVD (ft): 12714, 9782.29 No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 ' 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 Steven Cinelli Email Steven.Cinelli @BP.Com Printed Name ,' j , Steven Gina Title Production Engineer Signature L . � � /��hone 564 -5919 Date Prepared by Garry Catron 5644424 G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3■ Z- t4 2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No It Subsequent Form Required: /6 4 -0- APPROVED BY Approved by: COMMISSIO THE COMMISSION Date: / l — 1 S — / Z A { O f irt PP e d pP / i t " - /� a t PP � p v A roved a lication is valid for 12 months from the date of a r a . _ Su b in Duplicate Perforation Attachment ADL0047503 Well Date Perf Code MD Top MD Base TVD Top TVD Base 3- 41/K -39 7/14/07 RPF 13134 13154 10075 10089 3- 41/K -39 7/14/07 APF 13154 13162 10089 10095 3- 41/K -39 7/14/07 RPF 13162 13182 10095 10108 3-41/K-39 10/22/07 BPP 13412 13421 10269 10275 3- 41/K -39 10/22/07 BPP 13426 13442 10279 10290 3- 41/K -39 10/22/07 BPP 13532 13534 10352 10354 • 3-41/K-39 10/22/07 BPP 13534 13624 10354 10418 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS 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 0 Casing Summary ADLOO475O3 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 92 20" x 30" 39 131 39 131 LINER 1003 7" 29# NT95HS 12757 13760 9814 10514 9690 7820 NT -95HS PRODUCTION 12986 9 -5/8" 47# NT95HS 37 13023 37 10000 8150 5080 NT95HS SURFACE 2467 13 -3/8" 68# L -80 38 2505 38 2503 5020 2260 L -80 TUBING 134 4 -1/2" 12.6# L -80 12714 12848 9782 9879 8430 7500 L -80 TUBING 12677 5 -1/2" 17# L -80 37 12714 37 9782 7740 6280 L -80 • • • : by • • 0 To: Clark Olson/Tyler Norene - AK Well Services TL Nov 7, 2012 Jerry Bixby /Rob Liddelow — AK Wells Wireline TL From: Michael Hibbert, Well Interventions Engineer CC: Steven D. Cinelli, Endicott APE Subject: END 3-41 SBG, Underreaming, FCO, & Acid Wash Cost: AFE: AENINJEC IOR: 150 bopd 1 Endicott is an elevated risk area. Please ensure that SOP: Wellwork at • Elevated Risk Areas is followed. Sundry Required — Verify that a copy is included on job loacation. 1 D Take 1 gallon sample to SLB lab for emulsion and sludge testing. 2 F Schmoo -B -Gone treatment 3 S Pull 5.5" MCX SSSV, D &T, and memory caliper. Set S/O GLV @ 4361'. 4 D Connect GL and perform TIFL 5 C Coil and ASRC - Underream, FCO to 13678' MD, and acid stim w/ treating packer 6 S D &T. Pull S/O and set DGLV at 4361', SSSV. MIT -IA. Set 5.5" MCX 7 S Memory (PROF after well has been injecting for 1 week. Well Detail Current Status: Operable Injector Last Test: 19,540 bfpd gross liquid, 2145 psi WHIP, 149° F WHT. Max deviation: 53° at 8,383' MD. Angle at Top Perf: 47° at 13134'MD. (existing) 55° at 12965 'MD (top add pert interval) Min. ID: 3.725" at 12806' MD at 4 -1/2" XN Nipple Last TD tag: 06/04/07 13,536' CTMD Latest H2S 230ppm to 260ppm on A/L and gas injectors. SSSV status: Installed on 10/23/07; 5 -1/2" MCX at 1564' MD BHP /BHT: 5154 psi @ 10000' SS (13,065' MD) 155° F: obtained 08/23/07 after 9 days SI time. Data from adjacent wells: END 3 -39: 4077 psi @10,000' SS, 213° F, 06/26/2012; K2A • • • END 3 -15: 4275 psi @ 10,000'SS, 216 ° F, 06/22/2012; K2B Job Objective: The objective of this procedure is underream and remove the hard fill from approximately 13,536'MD to 13,678' MD (PBTD) and restore injectivity into the Kekituk K2A sands. Discussion: END 3 -41 is an Kekituk 2A/2B/3A2 injector that was drilled and completed in February 1989. The well was never produced and has injected 27mmbw into the 2A, 138mmbw into the 2B, and 0.3mmbw in the 3A2. The well was initially perforated to the 2A and the lower portion of the 2B, and initially the 2A took about 40 percent of the injection. Over time that fraction decreased and in 1992 an IPROF indicated that the 2A was taking only 9 percent of the injection. The 2A was subsequently reperfed, but there was very little increase is 2A injection afterwards. In June 2007 the 3A2 was perforated, and a bridge plug was set over the 2A/2B perforations. This bridge plug was pulled in October 2007, and a subsequent IPROF indicated that the 2B was taking 80 percent of the injection, and the 2A was taking only 20 percent of the injection. On 06/04/2007 while doing an SBC and FCO, coil discovered a hard spot in the bottom of the well at 13,536' MD. An attempt to jet through the hard spot was not successful, and coil moved off the well. This well currently has a Furmanite wrap on the starting head. Do not pump methanol or methanol blend into the OA due to chemical incompatibility with the epoxy resin in the wrap. Do not MIT -OA greater than 1200 psi due to the wrap rating. For questions or comments please call: Michael Hibbert at 564 -4351 (c) or 564 -4351 (w) Steve Cinelli at 564 -5919 (w) or 240 -0713 (c). CC: Well File Procedure: DHD 1. Collect 1 gallon oil sample from offset producer END3 -39 for an emulsion and sludge testing with 12% HCL and 9:1 mud acid recipes located further down in the procedure. 2. Deliver to SLB Lab. Fullbore Note: Do not exceed 3500 psi max pump pressure. Order SBG as hot as possible. 1. MIRU FB. 2. Spear in 5 bbls 60/40 methanol 3. Pump in 200 bbls Schmoo -B -Gone treatment followed by 5 bbls of 60/40 freeze protect at max rate. 4. Let soak for at least three hours 5. Return well to ops and POI. • • • 6. RDMO FB Slickline 1. SI Well. 2. MIRU SL. 3. RIH and pull 5'/2" MCX SSSV from 1564' MD. 4. D &T TD with 3.7" gauge ring and TEL. 5. Memory caliper 7 ", 4 -1/2" and 5 -1/2" tbg /liner. 6. Pull DGLV from 4361' and run a 8/0. 7. RDMO SL. DHD 1. Connect GL from neighboring well and perform TIFL. Coil 1. MIRU CTU and ASRC. o If Slick line could not drift through 4 -1/2" tubing with at least 3.70" drift, run 2 -7/8" motor and 3.70" 3 bladed junk mill to clear tubing before proceeding as below. o RU ASRC so that returns can be sent to flowline of adjacent well (3 - 23, 4 - 18,3 - 19, 4- 26 whichever allows for more efficient rigup). Plan on taking all returns when using lift gas through ASRC. o If returns are manageable without lift gas then flow to tanks if wind /H2S issues are manageable. Otherwise take all returns through ASRC. 2. MU BHA with 2.5" DJN w/ good hydraulic horsepower. 3. RIH and tag TD. (Top of hard fill last observed at -13536' MD. Also reference recent SL tag.) 4. PUH 50', establish 1:1 returns and RIH jetting fill from well bore 5. Spot 10 bbls of Geovis gel as required to help carry fill to the surface. 6. Once 13,678' or deeper is achieved pump 20 bbls gel sweep and POOH chasing fill to surface at 80 %. 7. If DJN cleanout is successful, proceed to step 19 (Acid Stim). If not, proceed to step 8 (CT Underreaming). 8. MU BHA with 3 -1/8" CTC, 3 -1/8" DCV, 3 -1/8" Jars, 3 -1/8 ", Disco, 3 -1/8" Dual Circ Sub, 3- 3/8" Motor, 3.625" Baker DB underreamer w/ -3.7" bit and near full opening UR arms to cleanout 7 ". 9. Shut in well and RIH without pumping to gently tag top of hard fill. Flag pipe at hard fill and tie into corrected SL tag. Paint good flag and try to use as depth correction for treating packer set. If flag is unusable on the way out of hole then an additional memory tie -in run will be required prior to setting the treating packer and acid stimulation. o Ensure to record the tagged depth 10. PUH 50' above TD and begin pumping to establish free spin. • • 11. RIH and begin underreaming on hard fill per PE Manual guidelines. This is likely a hard crust on top with softer fill beneath. Treat all progress deeper than initial tag as fill. Do not increase ROP above —30 feet per hour. If ROP increase and no motor work is seen then the decision can be made to POOH and swap to a nozzle, but UR'ing slowly will likely be the fastest method to remove this fill. Divert to tanks when gel hits surface or significant solids are seen in the returns. 12. Gradually increase pump rate as per Baker Engineer's recommendation using slick 1% KCI to begin milling hard fill. 13. Pump 15 -20 bbl gel sweep every 1 -2 bbls of fill. 14. Once at target TD (13678' ELMD) or if ROP starts decreasing rapidly, PUH and backream to 10' above CT initial tag depth. 15. RBIH to target TD and pump 20 bbl Geovis sweep then follow up with slick 1% KCL and circulate bottoms up to ensure debris are swept to the surface. 16. Shut down pumping and pull up into the 4.5" tubing to ensure the DB underreamer will close, if it closes RBIH to target TD. 17. Drop ball to open circ sub and pump another 20 bbls of Geovis, POOH chasing solids to surface at 80 %. After POOH, SI well. 18. Determine if flag is still usable at corrected SL depth where hard fill was tagged. Repaint if possible. Stimulation Target Open Perforations Zone MDT MDB H 2A 13532 13624 92' Total Footage 92' Design Basis Wellbore Volume 326 bbls to top pert at 13,532' Volume Across Perfs 3.4 bbls Acid Design 30 gpf of 12% HCI / 9:1 Mud acid Diversion Treating packer w/ spotting valve Overflush Design 90 gpf of NH4CI w/ F103 Fluid Requirements: Total Volumes for Acid Fluid Type Vol (bbl) Vol (gal) NH4CI + F103 730 30,660 12% HCI 65 2,730 9:1 Mud Acid 65 2,730 12% HCI (If CT has not been pickled before) 5 210 Fluids: Acidizing Fluids for bp Alaska — recommended additive concentrations Temperature: Low (ambient to 175 °F) _ Completion ;N: 180 Loading for: 12% HCI 9/1 mud acid Product Code: Function: Units: A264 ACl gaUMgal 4 4 A201 kibibitor Aid gaUMgaI 0 0 A153 k'itensher Ib/MgaI • 0 0 F103 Flowback aid gaUMgal • 2 2 L058 kon Control IbWMgal • 20 20 W054 Antiemisiter gaUAAgaI • 5 5 0067 Solvent gaVMgal 0 50 Acidizing Comments: • Filter all fluids possible that will enter the formation to 3 microns at place of origin. • Do not add friction reducer to stimulation fluids that will enter the perforations. • Do not exceed 0.65 psi /ft gradient during liquid packing or any other time during the job. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Send an electronic copy of the treatment report to Steven.Cinelli @bp.com CT Acid Stim 19. If depth control flag was unusable then perform memory tie -in pass. MU gamma- ray /CCL. Paint flag at 13,387'. POOH. 20. Bleed IA to 1000 psi to ensure that gas will not enter wellbore during IBP set and acid treatment. • . 21. SI well at lateral and wing valves. PT and pickle CT with 3 -5 bbls 12% HCI (if this coil string has not been pickled before). 22. MU treating packer with spotting valve. MU lubricator and PT. 1. x w li r volume with NH4CI water (500 bbls 23. Bullhead 5 e bo e ( bbls) down CT backside. 24. RIH and set treating packer at 13487'. 25. Before pumping acid, hold a pre -job safety meeting. 26. Pump the following acid job down CT at maximum rate (below 0.65 psi /ft frac gradient). Pumping Schedule Stage Cum Fluid Fluid Vol Vol Step Description Fluid bbl bbl 1 Pre -flush 3% NH4CI + F103 30 30 2 Acid 12% HCI acid 65 95 3 Acid 9:1 Mud Acid 65 160 4 Overflush 3% NH4CI + F103 200 360 27. Release treating packer. POOH. 28. RDMO CT. Slick Line 1. MIRU SL and Fullbore. 2. Load IA w/ inhibited seawater and a methanol cap. 191 bbls down to live GLV. Should be liquid packed beneath that. 3. MIT -IA CGz a rfi 30 ^� 4. D &T w/ TEL. 5. Pull S/O from 4361'. Run DGLV at 4361'. 6. Re -Set 5 -1/2" MCX SSSV at 1564' MD setup for 20,000- 28,000 bwpd. 7. RDMO SL Put well on injection for 1 week before proceeding with the (PROF. Slickline 1. RU SL 2. Pull 5.5" MCX from 1564'. 3. D &T 4. MU memory IPROF tool string including FB spinner /inline spinner /pressure /temp /CCUGR. 5. RIH and make a down pass with the well injecting at a constant rate as close to the well's normal injection rate (20,000 to 26,000 bwpd) as possible. Typical WHIP is 2000 psi. Do not exceed 3500 psi WHIP. 6. Make spinner up and down passes at 40, 80, and 120 FPM from 13,000 MD to 13,650' MD. • • 7. Perform stop counts at the following depths • 13100' MD • 13200' MD • 13422' MD • 13500' MD • 13650' MD 8. Repeat data collection from steps 5 and 6 at half of the initial injection rate 9. SI well. POOH and check for good data 10. Re -Set 5 -1/2" MCX SSSV at 1564' MD setup for 20,000- 28,000 bwpd. 11. RDMO. Return well to injection at 2000 WHIP. IPROF Log Presentation: 1. Job comments: a. Operating steps in sequence b. Rate control valve setting, percent opening, and injection rate c. Wellhead injection pressure and temperature d. Logging passes executed e. Field data interpretation 2. In the header for each pass, include a summary of the injection conditions 3. Include a flowing up pass overlay, flowing up /down pass overlay, and stop counts. A WELLHEAD = MCEVOY • S Y NOTES: H2S READINGS AVERAGE 230 - 260 ACTUATOR = AXELSON E N D 3 -41 A PP ON SSSV * 4/ COM POSIT WRAP REPAIR SH L - DO B. ELEV = 55.3' I 1 NOT PUM P M ETH/M ETH BLEND INTO OA DUE TO BF. ELEV = 16.5' ... • CHEM INCOMPATIBILITY w /EPDXY RESIN IN WRAP Max Angle = 53° @ 8383' 5 -1/2" CHROME NIPPLES *' Datum MD = 13105' 1564' H5-1/2" HRQ SVLN (9 -CR), ID = 4.562" I Datum TVD = 10000 SS 13 -3/8" CSG, 68 #, L -80 BTRS, -1 2505' ID = 12.415" GAS LIFT MANDRELS ST MD TVD DEV VLV LATCH PORT DATE Minimum ID = 3.725" @ 12806' 2 4361 4141 48 RP RK 0 08/04/94 1 12561 9667 40 DMY RK 0 08/04/94 4 -1/2" HES XN NIPPLE 12632' H5-1/2" HES X NIP (9 -CR), ID = 4.562" I 5-1/2" TBG, 17 #, L -80 NSCT, -I 12695' I I 12695' H 9 -5/8" X 5 -1 /2" TIW OVERSHOT I .0232 bpf, ID = 4.892" 12712' H9-5/8" X 5 -1/2" TM/ LATCH I 12714' 1-19-5/8" X 5-1/2" TIW HBBP PKR. ID = 4.75" I 1 I 12765' 1-14-1/2" OTIS X NIP, ID = 3.813" I I 12806' 1-14-1/2" OTIS XN NIP, ID = 3.725" I I TOP OF 7" LNR I 12767' 4 -1/2" TBG, 12.6 #, L -80, — I 12848' I 1 12848' H4 -1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" 9 -5/8" CSG, 47 #, NT95HS NSCC, ID = 8.681" H 13023' 1 PERFORATION SUMMARY REF LOG: DLL -GR on 12/31/88 & CBT on 01/05/89 ' ANGLE AT TOP PERF: 47° @ 13134' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE P 2-7/8 5.5 13134 - 13182 0 07/14/07 ' 3 -3/8 6 13412 - 13421 0 06/13/89 ' P. 3 -3/8 6 13426 - 13442 0 06/12/89 1 13459' I- 7" MARKER JOINT I ir 3 -3/8 6 13532 - 13624 0 02/28/93 — w--� ; 13 I -1CTU FCO HARD TAG (06/02/07) I 1 \4. --- i36.7 ko PBTD I 13678' 1'1'IV'1'1'1'1'; 1 7" LNR, 29 #, NT95HS, -1 13760' 1.0.0.40.1.1 .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 02/09/89 JLH ORIG COMPLETION 10/21/07 BSEJPJC PULL IBP /FISH (10/21/07) WELL: 3 -41 / K -39 04/24/07 JMF ADFERF 12/28/10 AW /JMD FORMAT REVISION PERMIT No: 1881260 06/08/07 TEL /PAG SET BKR IBP @ 13320' 02/24/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 21878 -00 -00 07/19/07 JMF /PJC PERFS (07/14/07) 08/15/11 DW /JMD ADDED H2S SAFETY NOTE SEC 8, T11 N, R17E, 2504' FNL & 650' FEL 08/17/07 JCM/PJC ELM TT LOGGED (07/22/07) 08/22/11 MV/ PJC COMPOSITE WRAP SFTY NOTE 08/17/07 SRB /PJC FISH (07/24/07) BP Exploration (Alaska) S.. • Minilog for Well Techl®g 3-41 K -39 Project [NENCOTT _ At II, lAU1EAJ, LARSOH ' . 5Cde 1!00 1 ■•• 6.14'2012 I Injector Well; 3-41_K-39 wr1: won- 2117500 EM . Ate 95 y- 277270.45 ; KJ4.04 1011 -11 -a 00:00:00 Coun73 USA Sion: name : 3-4170-34 E41 1 •, ,iaru,,.. K61114 .ta M r. 917402214 c336.el s., do. IaBD - 01.0! O60b00 1 . EN ICOTT Lan.) name: 141111-21 1.40 4140 INratl.o Aa44: lrnj:vh - 147.041141 S- 0,,.. Rate : Al., R,tal depth: 11740 'Mitt, lo 7.722774 :i... 102A Cmn4n.: wok o = NEI! W OA t.1! r iit 4N .6ft V1 , zi1 CA TVDSS MO C INS ONO Or ht K 1.41 Y.ror.( (FE E TI thr PE Notes sw i ^^ ,,. if - 1:900 1 90 • • ers at {AI7 1w ro1 . L 1,ae [. to nssr un i 1;100 10■00 'a.w -- ,11: s: ax :x 4 -"� 1 1!00 Tom .. •10100 I 11700 -10700 11400 1� illllllllll . N IP, { 1 Treating packer _., iii_..,1 set depth i s ' . 10190 (.! Perfs to be E ' stimulated. 4111111 � • 104 • 99 j ., _. 13700 i n ...c. II 1. 1 713➢ • 3- STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate[] Other Q FURMANITE WRAP Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ waiver[] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ — 188 -1260 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑� 6. API Number: _ Anchorage, AK 99519 -6612 50- 029 - 21878 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 047503 3- 41/K -39 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 13760 feet Plugs (measured) None feet true vertical 10514.34 feet Junk (measured) None feet Effective Depth measured 13678 feet Packer (measured) 12714 feet true vertical 10455 feet (true vertical) 9782 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 30" SURFACE - 131 SURFACE -131 Surface 2466' 13 -3/8" 68# L -80 SURFACE - 2505 SURFACE - 2503 5020 2260 Intermediate 12984' 9 -5/8" 47# NT80S SURFACE - 13023 SURFACE - 10000 6870 4760 Production Liner 993' 7" 29# SM -110 12767 - 13760 9821 - 10514 11220 8510 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 SURFACE - 12714 SURFACE - 9782 4 -1/2" 12.6# L -80 12714 -12848 9782 -9879 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X 5 -1/2" TIW HBBP PKR ( 9782 E 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4831. Q & 6n, (Rom Treatment descriptions including volumes used and final pressure: ! 1 A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 17,948 2033 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Stratigraphic ❑ Daily Report of Well Operations X I ll 6. Well Status after work: Oil LJ Gas LJ WDSPL EJ GSTOR ❑ WINJ Q WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na Joe astufl a Title Data Manager Signatur Phone 564 -4091 Date 11/22/2010 L 1A RMMS NOV 16 20N Form 10 -404 Revised 10/2010 •- / w . , ? � - /0 Submit Original Only #pf t 0I ✓� 1 3-41/K-39 188 -126 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tor Tvd Depth Bas 3- 41/K -39 1/6/89 PER 13,532. 13,624. 10,352.34 10,417.55 3- 41/K -39 6/12/89 APF 13,412. 13,421. 10,269.21 10,275.42 3- 41/K -39 6/12/89 APF 13,426. 13,442. 10,278.86 10,289.88 3- 41/K -39 2/28/93 RPF 13,534. 13,624. 10,353.75 10,417.55 3- 41/K -39 4/24/07 APF 13,162. 13,182. 10,094.55 10,108.45 3- 41/K -39 4/24/07 APF 13,134. 13,154. 10,075.26 10,089.02 3- 41/K -39 6/8/07 BPS 13,320. 13,330. 10,205.38 10,212.35 3- 41/K -39 7/14/07 RPF 13,162. 13,182. 10,094.55 10,108.45 3- 41/K -39 7/14/07 RPF 13,134. 13,143. 10,075.26 10,081.44 3- 41/K -39 7/14/07 RPF 13,143. 13,162. 10,081.44 10,094.55 3- 41/K -39 10/22/07 BPP 13,320. 13,330. 10,205.38 10,212.35 . i AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 3- 41/K -39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/24/2010IT/I/O = 10/0/160. Temp = S1. Bleed OAP to 0 psi (Furmanite Prep). OA FL near Isurface. Bled OAP to 0 psi in 2.5 hr (gas /2 bbls fluid). S1, monitored for 30 min. No change in OAP. Job complete. Final WHPs = 10/0/0. SV, WV =C. SSV, MV =O. IA, OA =OTG. NOVP. F � 3 E 10/25/2010!T/I/0 =0 +10110. SI. Bleed OAP to 0 psi (Furmanite prep). Bled OAP — to - O psi in 10 Imins, continue to hold open bleed on OA for 1 hr. S1, monitor for 30 mins, OAP lincreased 2 psi. Flow line blocked in @ manifold and bled to 0 psi. Clean residual [ ;fluid from starting head. Sombrero installed. Cellar is clean and dry, it is - 48" deep. ;Grating can be removed and cross braces unbolted. Final WHPs= O +/0/2 1Job complete ;SV,SV =C. SSV,MV =O. IA,OA =OTG. NOVP 10/26/201 IT /1 /0= 5/2/29. Temp= S1. WHPs (Pre Furmanite). No AL. TBG pressure increased 5 psi, IAP increased 2 psi, OAP increased 27 psi overnight. S SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. j F I 10/27/20101T/1/O= 5/2/67. Temp =S1. Bleed OAP to — 0 psi (monitor 1 BUR). OAP increased 38 psi over night. OA FL near surface. Bled OAP to 0 psi in 10 mins fluid to surface. Hold open bleed on OA for 1 hr. SI OA bleed and monitor every 15 mins for 1 hr (see log for details). OAP increased 11 psi in 1 hr. Job Complete Final WHPs 0 +/2/11. i SV,WV =C SSV,MV =O IA,OA =OTG NOVP i 10/28/2010 T/1/0= 5/2/75. Temp= S1. WHPs (post OA bleed). No AL. TP and IAP unchanged, OAP increased 64 psi overnight. 1 SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 10/29/2010 T /1 /0= 10/0 + /40. Temp= S1. WHPs (hang do not bleed tags). No AL. Tags hung I P ( 9 s 9) 9 9 on IA & OA casing valves. S SV & WV =C. SSV & MV =O. IA & OA =OTG. NOVP. 10/31/2010iT/1/0= 10/0 +/140. W Temp= S1. WHPs (OA BUR). No AL (Inj). OAP increased 20 psi .since last night. ;SV & WV =C. SSV & MV =O. IA & OA =OTG. NOVP. 10/31/20MTl0= 10/0 +/120. SI WHPs (OA BUR). No AL. OAP increased 80 psi from 10- 29 -10. 1SV,WV =C. SSV,MV =O. IA,OA =OTG. NOVP i 11/1/2010 T /1 /0= 10/0 +/140. Temp =Sl. Bleed OAP to 0 psi (pre Furmanite). OA FL @ surface. Bled OAP to 0 psi. Hold open bleed for 1 hr ( .5 bbl returns). Monitor for 30 mins, OAP increased 15 psi. Job Complete. Final WHPs 10/0 + /15. ,SV,WV =C SSV,MV= OIA,OA =OTG NOVP 1W1/3/2010T/I/O= 5/3/105. Temp= SI. Prep cellar, wellhead & remove floor grating. Bleed IA & SOAP to 0 psi (Furmanite Repair). IA & OA FL @ surface. Bled OAP from 105 psi to !0+ psi in 1 hour. Maintained open bleed on IA & OA together for additional 1 hours. jCleaned area above & below lower SH. Removed sombrero spill containment from Icellar, spray in liner in place. Removed floor grating, installed heater trunk into cellar j Ithen covered cellar w/ visqueen. Monitored for 30 minutes, IAP unchanged, OAP increased 10 psi. Final WHPs= 3/0/10. Job completed. 'SV,WV= closed. SSV,MV =open. IA,OA =open to gauge. NOVP. i 11/5/2010IT/1/O= 5/2/120. Temp= S1. Bleed IA & OAP to 0 psi, install N2 cap on OA — 50' (Furmanite wrap). IAP increased 2 psi, OAP increased 110 psi in two days. IA & OA FL @ surface. Bled IAP to 0 psi in 5 minutes. Bled OAP from 120 psi to 0 psi in 20 minutes. Rigged up N2 to OA, increased OAP from 0 psi to 25 psi in 1 minute. I Monitored for 30 minutes. OAP unchanged, OA FL decreased slightly still near I 'surface. Final WHPs= 5/0/25. SV,WV= closed. SSV,MV =open. IA,OA =open to gauge. NOVP. 1 I 11/6/2010.T/I/O= 10/5/90. Temp= SI. Assist w/ Furmanite wrap (SH repair). OAP increased 65 Ipsi, OA FL rosed to surface overnight. Held PJSM. Prepped SH and SC for sand blasting. Sand blasted SH & SC. Furmanite techs applied e- glass. See log for details. Night crew will continue monitoring. E [ 11/7/2010T/I/O= 10/0/0. Temp = SI. Assist w/ Furmanite wrap (SH repair). OA FL @ surface. i aHold open OA bleed to mitigate OAP increase & monitor. Furmanite techs applied ; !first layer of carbon fiber. See log for details. Day crew will continue monitoring. lContinued on WSR 11 -7 -10. !Job Continuing..... i r _.__ _ 11/8/2010'T/l/O= 10/5/3. Temp= SI. Assist w/ Furmanite wrap (SH repair). OA FL @ Surface. Monitor OAP & hold open bleed to mitigate OAP increase. See log for details. Day screw will continue monitoring. Continued on WSR 11 -7 -10. !Job Continuing..... 11/9/2010tT/I/O= 10/3/4. Temp =S1. Assist w/ Furmanite wrap (SHrepair). OA FL @ Surface. Monitor OAP & hold open bleed to mitigate OAP increase (see log for details). j Continued on day -shift. The final Furmanite wrap was completed @ 1200 hrs. Begin 7 day cure. I ** Job to be continued on night shift ** 11/10/2010!T/I/O SSV /3/4. Temp =Sl. Assist w/ Furmanite wrap (SH repair). ** Continued from previous days AWGRS. OA FL @ Surface. Open bleed on OA while furmanite cures. * *See log for details. E 11/11/201 0= SSV /3/4. Temp =Sl. Assist w/ Furmanite wrap (SH repair). "Continued from previous days AWGRS. OA FL @ Surface. Open bleed on OA while Furmanite I * cures. See log for details. 11/12/2 0 T /I /O = 1000/0/4. Temp = 90 °. ** *Continued from previous day's AWGRS. Assist l w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. �11/13/2010T/I/O = SSV /0/4. Temp = SI. ** *Continued from previous day's AWGRS. Assist €w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. j 11/14/2010!T/I/O = SSV /0/4. Temp = SI. ** *Continued from previous day's AWGRS. Assist �w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. 3 11/15/2010'T/I/O = SSV /2/2. Temp = SI. ** *Continued from previous day's AWGRS. Assist 'w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. E 11/16/2010T/I/O = SSV /2/2. Temp = SI. ** * Continued from previous day's AWGRS. Assist 1w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. Shut -in OA 3 bleed and rigged down, end of curing process. See log for details. Final WHPs= SSV /2/1. !Job completed. !SV,WV,SSV= closed. MV =open. IA,OA =open to gauge. NOVP. I E - . — _�....�. - ..1/.. 30 ..�. --, 120 . LED � O 11/19/2010T/I/0 = SSV /0 +/1 30. Temp = SI. MIT -OA to 1200 psi FA .,— ILED (SH repair). --- OA FL @ surface. Pumped 1.3 bbls of diesel to pressure up OA to 1200 psi in 5 min. 1st attempt OAP lost 50 psi in 1st 15 min, and 30 psi in 2nd 15 min fora total loss of 80 I psi in 30 min. Repressure OA to 1200 psi. 2nd attempt OAP lost 30 psi in 1 st 15 min and 20 psi in 2nd 15 min for a total loss of 50 psi 30 min. Repressure OA to 1200 ' psi. 3rd attempt OAP lost 30 psi in 1st 15 min and 20 psi in 2nd 15 min and 10 psi in 13rd 15 min for a total loss of 60 psi n 45 min (see log for details). No signs of diesel Ishowing on on Furmanite wrap. MIT failed due to pressure loss with no signs of diesel leaking through Furmanite. Bled OAP from 1140 psi to 0 psi in 10 min. During 1 'bleed IAP remained unchanged. Monitored for 30 min, OAP increased 40 psi. Gave !well back to PO as per WIE. Job complete. Final WHPs= SSV /0 +/40. SV, WV, SSV= Closed. MV= Open IA, OA= OTGNOVP_ 11/20/2010 T /I /O= 2100/0/780. Temp= Hot. Monitor SH for leaks (Post Furmanite). No signs of leaking on Furmanite. PO bled OAP to 100 psi @ 16:00. SV= Closed. WV, SSV, MV= Open. IA, OA= OTG. NOVP. FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL WELLHEA AMC SON J M D D RA F 9 END 3 -41 S ES: ***5-1/2" CHROME NIPPLES * ** KB. ELEV = 55.3' BF. REV= 16.5' KOP 1564' 5 -112" HRO SVLN (9 -CR), ID = 4.562" Max Angle = 53° @ 8383' Datum MD = 13105' Datum TV D = 10000 SS 13 -3/8" CSG, 68 #, L -80 BTRS, 2505' ID = 12.415" GAS LIFT MANDRELS STI MD I TVD I DEV I VLV I LATCH I PORT DATE 2 1 4361 1 4141 48 RP I RK 0 08(04194 1 12561 9667 40 DMY RK 0 08!04/94 Minimum ID = 3.725" @ 12806' 4-1/2" HES XN NIPPLE 12632' 5-1/2" HES X NIP (9 -C R), ID = 4.562" 5 -1/2" TBG, 17 #, L-80 NSCT, 12695' 12695' 9 -5/8" X 5 -1/2" TM! OVERSHOT .0232 bpf, ID = 4.892" 12712' 9 -5/8" X 5 -1/2" TMI LATCH 12714' 9 -5/8" X 5 -112" TIW HBBP PKR, ID = 4.75" 12765' 12806' 4 -1/2" OTIS XN NIP, iD = 3.725" TOP OF 7" LNR 12767` 4 -1/2" TBG, 12.6 #, L -80, 12848' J 12848' 4 -1/2" WLEG, ID= 3.958 .0152 bpf, ID = 3.958" 9 -5/8" CSG, 47 #, NT95HS NSCC, ID = 8.681" 13023' PERFORATION SUMMARY REF LOG: DLL -GR on 12/31/88 & CBT on 01/05/89 ANGLE AT TOP PERF: 47" @ 13134' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8 6 13134 - 13154 O 04/24/07 2 -7/8 5.5 13134 - 13182 O 07/14/07 2 -7 /8 6 13162 - 13182 O 04/24/07 13459' 7" MARKER JO 3 -318 6 13412 - 13421 C 06/13/89 3 -318 6 13535 - 13624 C 02/28193 PBTD 13678' 7" LNR, 29 #, NT95HS, 13760' .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 02/09189 JLH ORIG COMPLETION 10/21/07 BSE/PJC PULL IBP /FISH (10/21/07) WELL: 3 -41 / K -39 04/24/07 JMF ADPERF 11/08/10 JMD FORMATREVISION PERMIT No: 1881260 06/08/07 TEL /PAG SET BKR IBP @ 13320' AN No: 50- 029 - 21878 -00 -00 07/19/07 JMF /PJC PERFS (07/14/07) SEC 8, T11 N, R1 7E, 2504' FNL & 650' FR 08/17/07 JCM/PJC 1 ELM TT LOGGED (07/22/07) 08/17/07 SRB /PJC I FISH (07/24/07) BP Exploration (Alaska) OPERABLE: Injector END341 (PTD #1881260) Starting Head Leak Repaired Page 1 of 2 0 0 Maunder, Thomas E DOA From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, November 19, 2010 3:02 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES END Production Optimization Engineer; McLeod, Jennifer D; Wood, Alecia Cc: King, Whitney; Quy, Tiffany; Vazir, Mehreen Subject: OPERABLE: Injector END3 -41 (PTD #1881260 Starting Head Leak Repaired All, Produced water injector END3 -41 (PTD #1881260) recently had a composite wrap applied to the starting head to mitigate a small thread leak. The wrap has been pressure tested and there was no evidence of a continued leak at surface. In addition, an AOGCC witnessed MITIA passed on 08/03/10 verifying two competent barriers. The well has been reclassified as Operable and may be placed on production when convenient for operations. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 NOV � � ?DID Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, September 05, 2010 9:41 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES END Production Optimization Engineer; McLeod, Jennifer D Cc: Janowski, Carrie; King, Whitney; Quy, Tiffany; Vazir, Mehreen; AK, D &C Well Integrity Coordinator Subject: NOT OPERABLE: Injector END3 -41 (PTD #1881260) Confirmed Starting Head Leak to Atmosphere All Produced water injector END3 -41 (PTD #1881260) has been confirmed to have a startinghead leak to atmosphere. The well needs to be shut -in as soon as possible and remain so until it has been repaired. The well has been reclassified as Not Operable. Plan forward: 1. Evaluate for a composite wrap starting head repair A TIO plot and wellbore schematic have been included for reference. 11/19/2010 0 s Injector END3 -41 (PTD # 1881260) TIO Plot W.& 3-41 u00 �,bg t as O on + 000a o� u1 I I 65127/09 10/28/09 l9 /28/05 12/29N9 01129/10 03 /1i1 /i0 0,01/10 05/02/10 CAE /02i 10 07) 08,03110 09/033/10 MEMORANDUM • To~ Jim Regg ~ ~6 r,v P.I. Supervisor P( FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 04, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-41/K39 DUCK IS UNIT SDI 3-41/K39 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~'- Comm Well Name: DUCK IS UNIT SDI 3-41/K39 Insp Num: mitCS100804061512 Rel Insp Num: API Well Number: 50-029-21878-00-00 Permit Number: 188-126-0 Inspector Name: Chuck Scheve Inspection Date: 8/3/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3-41/K39 Type Inj. W ~ ~ TVD 9782 IA 360 2600 2580 2580 p.T.D~881260 TypeTQSt ~ SP i 1 TCSt pSl 2445 QA 160 240 240 240 Interval anzTST per, P ~ Tubing ~ ]sao ]s6o 1940 1860 ~ Notes: Wednesday, August 04, 2010 Page 1 of 1 10/30/07 ~~ih'~Ll~i~~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ni~n hti ~ I .,,, ne~~.c.,+hn n~ro NO. 4349 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt., Pt. Mac RI [:nln. rn L2-11 11686750 RST ~ # 05/24/07 1 1 3-41/K-39 11813054 RST ~ 06/09107 1 1 05-22A 11285946 MCNL ~ 10/19/06 1 1 P2-22 11649964 MCNL 'R S 04125/07 1 1 OWDW-SW 11211392 RST ($(Orj- 04/20106 1 1 W-213 40015198 OH MWD/LWD EDIT '~ 05/29/07 2 1 NLtASt AGKNVWLtUCit KtIaIF' I tSY 51(aNlNli ANU Kt I VKNINl9 VNt I:VYY tAGI"~ 1 V:,, BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ( *~ ~~91,}~~ b i !~o' ~°'~ ~, Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth ~d ' Received by: • • Scblumbepg8P UT~ 1~~-/Ð0 <. "-rVE=O RECEJ- 07/27/07 NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth JUL. 3 0 ZOOl l\IækaOil&GasCOl1s.commi~iXfl\t..\t:D AUG 0 1 2007 Anchorage Svl'\1" '!:.. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job# Loa Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/5-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: dlo ~ . STATE OF ALASKA .. .r~-ð~ ALASKA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS D D o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 3228 0 o 2104 0 15. Well Class alter proposed work: Exploratory Development 16. Well Status alter proposed work: Oil Gas WAG 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 3. Address: 55.3 KB 8. Property Designation: ADLO-047503 - 11. Present Well Condition Summary: Total Depth measured 13760 - feet true vertical 10514.34 feet Effective Depth measured 13678 feet true vertical 10455.98 feet Casing Length Size MD Conductor 92' 30" Surface - 131 ' Surface 2466' 13-3/8" 68# L-80 Surface - 2505' Intermediate 12984' 9-5/8" 47# NT80S Surface 13023' Liner 993' 7" 29# SM-110 12767' 13760' Perforation depth: Measured depth: 13134 - 13624 True Vertical depth: 10075 - 10417.55 - Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# 9-5/8" TIW o o o Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble ~~ <h O~ cr '/f,,; ~ ~ <. .~ Ö'~ õ> ~)' Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 188-1260 w 6. API Number: 50-029-21878-00-00 9. Well Name and Number: 3-41/K-39 10. Field/Pool(s): Endicott Field/ Endicott Pool - Plugs (measured) None Junk (measured) None TVD Surface - 131' Surface - 2503' Surface - 10000' 9821' - 10514' Burst Collapse 5020 6870 11220 2260 4760 8510 SCANNED JUL 3 1 2007 - - L-80 L-80 12695' - 12714' 12714' - 12848' 12714' o o o RBDMS BFL JUL 3 02007 Tubing pressure 2330 2397 Service w WINJ w WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Management Engineer Date 7/18/2007 Signature Phone 564-4944 evised 04/2006 0 R \ G \ N A L J,'I").G ¿::t!!..~.-r Submit Original Only . . .. 3-41/K -39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/14/2007****WELL INJECTING ON ARRIVAL**** INITIAL T/I/O = 2300/0/200. ¡PERFORATED FROM 13134 -13182 FT. USING SLB PURE GUN SYSTEM. 3- 13/8" GUN BODY WITH 2-7/8" CHARGE STRIP, 5.5 SPF 2906 PJ OMEGA :CHARGES, 0.5 SPF PURE PUNCHER CHARGES, OVERALL LENGTH OF GUN STRING #3 = 34 FT, MAX OD = 3.325 IN. FINAL T/I/O = 1125/0/120 ****WELL LEFT SHUT IN**** **** JOB COM PLETE**** FLUIDS PUMPED BBLS I 1 DIESEL 1 TOTAL Schlumberger SCANNED JUN 2 1 2007 NO, 4306 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UIC-/06 - 18Cô Field: Prudhoe Bay WI! L D CI CD D t BL J b# 'f e 0 og escnpllon ae o or L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESSITEMP SURVEY 06/06/07 1 Y -11 C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L 1 11686753 LDL OS/28/07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-3SA 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-0SA 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: ,11 ¡¡\! / ,0 ~Onl Received by: {)LI" ~~j-1 06/18/07 . . P.O. Box 196612 Anchorage, AK 99519-6612 ~ RECEIVED I STATE OF ALASKA $'0 3iIf ALAS Oil AND GAS CONSERVATION COM~IONMAY 0 2 2007 REPORT OF SUNDRY WELL OPERATIONS Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Class: Development Exploratory Stratigraphic Service .. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull TubingD Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Stimula WaiverD TimAIl~~ Re-enter Suspended Well D 5. Permit to Drill Number: 188-1260 3. Address: ¡;r 6. API Number: 50-029-21878-00-00 ' evation (ft): 9. Well Name and Number: 55.3 KB ' 3-41/K-39 . Designation: 10. Field/Pool(s): ADLO-047503 / 11. Present Well Condition Summary: Endicott Field/ Endicott Oil Pool ' Total Depth measured true vertical 13760 I feet 10514.34 feet Plugs (measured) Junk (measured) None None Effective Depth measured 13678 feet true vertical 10455.98 feet Casing Length Size MD TVD Burst Conductor 92' 30" Surface - 131 ' Surface - 131' Surface 2466' 13-3/8" 68# L-80 Surface - 2505' Surface - 2503' 5020 Intermediate 12984' 9-5/8" 47# NT80S Surface 13023' Surface - 10000' 6870 Liner 993' 7" 29# SM-110 12767' - 13760' 9821' - 10514' 11220 Collapse 2260 4760 8510 SCANNE[> MAY 0 9 2007 Perforation depth: Measured depth: 13134 - 13624 True Vertical depth: 10076 - 10418 - - - - Packers and SSSV (type and measured depth) 5-1/2" 17# 4-1/2" 12.6# 9-5/8" PACKER 4-1/2" SSSV o o L-80·· L-80 ., ............... 12695' - 12714' 12714' - 12848' 12714' 1566' o o Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS 8Ft MAYO 8 1007 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 30439 0 o 32219 0 15. Well Class after croposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG Tubing pressure 2506 2542 13. Service x Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature Title Data Management Engineer Printed Name Phone 564-4944 Date 4/30/2007 ORIGINAL k,ý; Submit Original Only . . 3-41/K -39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/21/2007 *** WELL INJECTING. ON ARRIVAL *** (PRE ADPERFS) DRIFT WI 2718 DMY GUN, TEL & S-BAILER TAG WLEG @ 12842' SLM (+ 6' CORRECTION = 12848' MD) STOP @ 13200' SLM (+ 6' CORRECTION = 13206' MD), NO SAMPLE RETRIEVED. NO EXCESSIVE PICK-UP WEIGHTS. (SWAB ISSUES, MAY NEED GREASE CREW OR HEAT (PRE JOB) ***WELL LEFT SII, TURNED OVER TO WELL TENDER*** 4/23/2007 WELL INJECTING ON ARRIVAL. ATTEMPT TO PERF FROM 13134' - 13154' AND 13162' - 13182' USING 2-7/8" HSD 2906 PJ OMEGA GUNS. JOB CONTINUED ON 24-APR-2007 AWGRS. ***JOB IN PROGRESS*** 4/24/2007 ADD PERF WELL INJECTING ON ARRIVAL. T.D IS GETTING SHALLOWER WITH EACH CORRELATION PASS. POSSIBLE SCHMOO AS T.D. IS SOFT BUT STICKY BOTTOM. INITIAL TIIIO = 250010/175 PERFORATE FROM 13134' - 13154' AND 13162' - 13182' USING 2-7/8" HSD 2906 PJ OMEGA GUNS. API DATA = ENTRANCE HOLE =.34", PENETRATION = 36" FINAL TIIIO = 120010/100 ***** JOB COMPLETE***** FLUIDS PUMPED BBLS I 1 DI ESEL 1 TOTAL MEMORANDUM TO: Camille O. Taylorr ~ Chair State of Alaska Alaska Oil and Gas COnservation Commission DATE: August 29, 2002 THRU: Tom Maunder ~,,~ . P.I. Supervisor \O'''(~)"~C~, [ SUBJECT: Mechanical Integrity Tests BPXA Endeavor / SDI 5-01/SD-7, 5-02/SD-10, 3-41/K39 FROM: Jeff Jones DIU Petroleum Inspector Endicott Field NON- CONFIDENTIAL ' Packer Depth Pretest Initial 15 Min. 30 Min. WoIII5-01/SD07 Type lnj.I G I T.V.D. I 8740 I Tubing I 4300 I 4300 I 4300 I 4300 I lntervall O P.T.D.I 80-120 TypeteStI P I Testpsil 2185 ICaSingI 1825I 2500I 2525I 2525I P/F I P Notes: 8 month interval. Test fluid: 3 BBLS methanol. '""' "Welll5-02/SD101Typelnj.I S I T.V.D. J 9093 I Tubing I zero I 2300 J 920 I 500 IlnterVall V ' P.T.D.] 181-118 TypetestJ P JTestp.siI 2273 JCasingI zero I 21001 800 I. 380'1 P/F I F Notes: 8 month interval, operated under variance. Test fluid:19 BBLS methanol. -- . ' WellI 3-41/K39 I Typelnj. I S I*.V.~. I,~0~ I Tubing 12500 I ~00 I ~,00 I~00 J lnterval P.T.D.I 88-126 Type testI P I Testpsil 2446 ICasingI 740 I 25001 24501 24501 P/F Notes: Test fluid: 5 BBLS methanol. 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. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details August 29, 2002: I traveled to BPXA's Endicott Field to witness MIT's on Endeavor Island and SDI injection wells. Mark Sauve was the BPXA representative for the tests, which were performed in a safe and proficient manner. The pre- test pressures on the three wells were monitored for 30 minutes with no significant changes noted. Gas injection well 5- 01/SD-07 and water injection well 3-41/K39 passed their MIT's. Water injection well 5-02/SD- 10 has known IA and OA casing leaks and is operated under an AOGCC variance. A CMIT was performed on this well and 19 BBLS of methanol was pumped into the 4.5"X 9 5/8" inner annulus and the pressure in the 9 5/8" X 13 3/8" outer annulus began tracking the IA pressure within +/- 120 PSI. A leak rate of approx. 0.4 BBLS/min. ~ 2300 PSI was noted. The IA / OA pressures dropped to 500 / 380 in 30 minutes and to 0 / 0 in approx. 45 minutes, failing the test. After consultation with Tom Maunder in the Anchorage AOGCC office and AOGCC Petroleum Inspector Lou Grimaldi, it was decided to shut the well in pending further diagnostics. Summary: ] witnessed 3 MIT's at BPXA's Endeaver Island and SDI in the Endicott Field, DIU. M.I.T.'s performed: 3 Attachments: none Number of Failures: Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. SCANNED OCT 0'& MIT DIU 5-01,5-02,3-41 8-29-02 JJ.xls 9/10/2002 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 E E C:LORIX,MFILM.DOC Pl~ E W M A T ER IA L U N D ER TH IS M A R K ER, STATE OF ALASKA ak~~,, OIL AND GAS CONSERVATION COMMI'~'~,'TN REPORT F'SUNDRY WELL, OF,_RATIONS 1. Operations performed: Operation shutdOwn Stimulate__ Plugging__ Perforate__ RECEIVED r Z~ 'mnn SEP v Pull tubing__ Alter casing __ Repair well __ Other X Alaska 0il & Gas Cons. 6. Datum elevation (D~lh~i~8 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchora.(Te, Alaska 99519-6612 5. Type of Well: Development __ Exploratory __ Stratigraphic ~ Service .. KBE = 55.3 feet 7. Unit or Property name Duck Island Unit/Endicott Well number 3-41/K-39 SD/ 9. Permit number/approval number 88-126/93-070 10. APl number 50- 029-21878 4. Location of well at surface 8. 2504' SNL, 650' WEL, Sec. 8, T11N, R 17E At top of productive interval 4658'SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539'SNL, 4319' WEL, Sec. 3, T11N, R17E 13760 feet 10459 BKB feet Plugs (measured) 12. Present well condition summary Total depth: measured true vertical 13678 feet 10401 BKB feet Junk (measured) Effective depth: measured true vertical 11. Field/Pool Endicott Oil Pool Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2466' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 12984' 9 5/8" 575 c.f. Class G 13023' 10000' 9821'- 10514' 993' 7" 420 c.f. Class G 12767'- 13760' measured 13412'- 13421', 13426'- 13442', 13532'- 13624' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297'- 10362' Casing Structural Conductor ;. Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' U iGINAL Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Mn"lA (8/9/98) Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 0 0 Tubing Pressure 0 0 14. Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil Gas__ Suspended__ Service w_~f_er Ini.~__C.f_nr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~. ~l~_l~s~ Title 5~eni~3r T. chnic~l A~;.,;i~tent IV Tel. ,~64--~.~4 Date 09/03/98 Form 10-404 Rev 06/lb-'~8 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 819/98. WELL N°: 3-41/K-39 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT IA LovelacelBarba Tri-plex TIME 1150 1200 1235 1245 OPERATIONS SUMMARY RIG UP Tri-plex AND P-TEST LINE TO 3000 PSIG SIWHP = 165, IA = 300. BEGIN PUMPING METHANOL DOWN IA and pressured up to 2500 ps~g. MONITOR FOR 30 MINUTE, PRESSURE HELD. Witnessed by John Spaulding of the AOGCC. SIWHP = 165, IA = 2500. GOOD TEST. BLED IA DOWN TO 300 PSIG & RIG DOWN Tri-plex. summary: Performed a IA MIT. Pumped methanol into the IA and held 2500 psi for 30 min. Bled inner annulus to 300 psi. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PLS FINAL BL+RF 1PLS FINAL BL+RF 1 SBT/GR FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 3235.07 Run # 1 5906.05 Run # 1 6452.02 Run # 1 6452.03 Please sign and return to: Attn. Rodn~~ ~ ~ervices Street ../~' ~uite 201 ~ // Anchorage, AK 99518 ~ Or~X to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 30 December 1994 Transmittal of Data ECC #: 5906.04 Sent by: MAIL Data: PDK Dear Sir/Madam, Reference: BP 3-41/K-39 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Run # 1 ~~ Please sign and return to: Attn. Rodney D/wPaulson Atlas Wire~e Services 5600 B~eet Suit~-~01 __ A/D~h~orage, AK 995~8 ~ FAX to (907) 563-7803 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMi~,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571' SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539'SNL, 4319' WEL, Sec. 3, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.3 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-41/K-39 SD/ 9. Permit number/approval number 88-126/93-070 10. APl number 50- 029-21878 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13760 feet 10459 BKB feet Plugs (measured) feet Effective depth: measured true vertical 13678 feet 10401 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True veBrt~l depth BKB 92' 30" Driven 131' 131' 2466' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 12984' 9 5/8" 575 c.f. Class G 13023' 10000' 993' 7" 420 c.f. Class G 12767'- 13760' measured 13412'- 13421', 13426'- 13442', 13532'- 13624' 9821'- 10514' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure NOV - 7 1994 0il & Gas Cons. Commission Anchora~i; 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 13398 0 223773 0 Tubing Pressure 1281 1613 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended ~ervice Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"'~;~?_~7.~ ~ ,~'/, ~ Title Senior TechnicalAssietantll Form 1 Rev 06/15/88 SUBMIT IN DUPL~/cA'~E ii Endicott Production Engineering Department OPERATIONS REPORT DATE: 8/20/94 WELL Nm: 3-41/K-39 TYPE OF OPERATION:' BP EXPLORATION REP: SERVICE COMPANY: MIT MCBRIDE N/A DATE/TIME OPERATIONS SUMMARY 1300 RIG UP PE TRIPLEX TO IA. WHP = 250 PSIG, IA = 300 PSIG. PRESSURE ON IA TO 2500 PSIG. WHP CAME UP TO 275 PSIG. AFTER 30 MINUTES IA WAS STILL 2500 PSIG AND TBG WAS STILL 275 PSIG. MIT PASSED. TEST WAS WITNESSED BY AOGCC REP JOHN SPAULDING. RECEIVED NOV -7 1994 A~ska Oil & Gas Cons. Commission Anchora;.,~,~ i STATE Of ALASKA ALAskA OIL AND GAS CONSERVATION COMMISS,uN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service .. ORtSiN L 6. Datum elevation (DF or KB) KBE-- 55.3 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-41/K-39 SDI 9. Permit number/approval number 88-126/9-466 10. APl number 50- 029-21878 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 13760 feet Plugs (measured) 1O459 BKB feet 13678 feet Junk (measured) 10401 BKB feet Size Cemented 92' 30" Driven 2466' 13 3/8" 3336 c.f. Permafrost 12984' 9 5/8" 575 c.f. C/ass G Measured depth True veBr~l depth BKB 131' 131' 25O5' 25O3' 13023' 10000' 993' 7" 420 c.f. Class G 12767'- 13760' measured 13412'- 13421', 13426'- 13442', 13532'- 13624' 9821'- 10514' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12695'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" TIW "HBBP" Packer at 12714'; 4 1/2" Otis SSSV at 1563' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure AUG 3 1 1994 Alaska 0ii & Gas Cons. Commission Anchora[/e 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operation/s X Oil Gas Suspended 17. I hel~by certify that the foreg~ng,.[s tr.,,ue and corr~ect to the best of my knowledge. Signed ~ Title Drilling Engineer Supervisor Form 10-404 Rev 06/15/88 Service Water Injector SUBMIT IN DdPLI~ATE ~. BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SDI 3-41/K-39 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 08/01/94 06:00 SPUD: RELEASE: 08/05/94 08:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 15 08/01/94 ( 1) TD:13760 PB:13678 08/02/94 (2) TD:13760 PB:13678 08/03/94 (3) TD:13760 PB:13678 08/04/94 ( 4) TD:13760 PB:13678 RIG UP MW: 8.5 Seawater SKID RIG F/3-21. WELL CNTRL INCIDENT ON 3-39 SUSPENDED RIG MOVE @ 1400 HRS T/INITIATE REPAIRS ON INTERNAL ANNUL. VALVE BEFORE MOVING RIG ONTO 3-41. STAND BY WHILE PE'S KILL WELL & REPLACE IA VALVE ON 3-39. SECURED PERMIT @03:00 T/MOVE RIG. RIG UP & ACCEPT @06:00 ON 8/1. POOH LD TBG MW: 0.0 Seawater PULL BPV, INSTALL TWC. ND TREE. CHECK THREADS ON TBG HNGR W/LNDG JT. NU BOP'S TEST. MU LNDG JOINT & BOLDS, PULL 310K T/COMP. DOWNHOLE CUT. PULL TWC & DSPLCE DSL F/HOLE. POOH LD TBG. RIH W/OVERSHOT MW: 0.0 Seawater LD 5.5" TBG & CLEAR FLOOR. TALLY SHOWS 92' OF FISH IS LEFT IN HOLE. TEST BOP'S PU FA%i & RIH PU REQUIRED DP T/REACH FISH. TAGGED FISH @12622. WORK FISH. CBU POOH & LD FISH. RECOVER 38.71' - PARTED @ CUT ATTEMPT %1. CUT LOOKS. CLEAN. GHANGE GRAPPLE & RIH T/1400. CUT DL. RIH W/OVERSHOT. RUN TBG MW: 0.0 Seawater RIH W/OVERSHOT TAG & LATCH ONTO FISH @12662. ROTATE & RELEASE LATCH ASSY F/TOP OF TIW PACKER. CBU POOH LD FISH. FISH = 7' CUTOFF JT, 1) 40' TBG JT. 1) PUP JT & LATCH RECEPICLE. RIH W/6-3/4" DC & 50 STDS OF 5" DP. POOH & LD DP & COLLARS. SERV. RIG. POOH & LD DP & COLLARS. PULL BOWL PROCTECTOR, RIH W/5.5" TBG & TIW PKR LATCH ASSY. Oil & Gas Cons. Commissior~ WELL : SDI 3-41 OPERATION: RIG : DOYON 15 PAGE: 2 08/05/94 ( 5) TD:13760 PB:13678 08/06/94 ( 6) TD:13760 PB:13678 FRZ PROTECT W/DSL. MW: 0.0 Seawater RIH W/5.5" TBG. LATCH INTO EXISTING PKR, TEST W/20K OVERPULL, TEST ANNUL T/2000. SHEAR VALVE W/40K OVERPULL. SPACE OUT TBG HNG. & TEST CONTROL LINE T/5K. DISPLACE ANNUL. W/TREATED SEAWATER. LAND TBG IN HANGER & SET LOCK DOWNS. LD LNDG JT, SET 2-WAY CHECK VALVE IN HNGR. ND BOPE & NU ADPTR FLNG. & MASTER VALVE. TEST CONTROL T/5K. TEST H NGR & MASTER VALVE T/5000. PUMP 101 BBLS DSL DOWN ANNUL, RU & U-TUBE DSL T/TBG. TREE WILL BE INSTALLED AFTER RIG MOVE BY PE'S. TEST WITNESS OF TREE & TBG WILL OCCUR @ THAT TIME/PER DOUG AMOS W/AOGCC. RIG RELEASED MW: 0.0 Seawater INSTALLED TWC, SECURED WELL, RELEASED RIG @08:00 HRS. SIGNATURE: (drilling superintendent ) DATE: I ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .__ Suspend Operation Shutdown __ Re-enter suspended well~ Alter casing __ Repair well __ Plugging __ Time extension Stimulate __ Change approved program Pull tubing x Variance ~ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504' SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658'SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measu red true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service X RECEIVED JUL 2 8 1994 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) KBE = 55.3 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-41/K-39 SDI g. Permit number 88-126/Conservation Order/1297 10. APl number 50-029-21878 11. Field/Pool Endicott Oil Pool 13760 feet 10459 BKB feet 13678 feet 10401 BKB feet Plugs (measured) Junk (measured) ORIGINAL_ feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~,~ Tru~rtical depth 92' 30" Driven 131' 131' 2466' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 12984' 9 5/8" 575 c.f. Class G 13023' 10000' 993' 7" 420 c.f. Class G measured 13412'- 13421', 13426'- 13442', 13532'- 13624' 12767'- 13760' 9821'- 10514' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 8/2/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended~ 17- I hereby certifY 4C~ that/~he foregoing is true and correct to the best of my knowledge. Signed _~,-.J Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test~ Location clearance Mechanical Integrity Test /x~ IApproval No. Approved by order of the Commission Subsequent form required 10- ~ O ~. Original Signed By David W. Johnston Commissioner Date ?~'Z ~'~' y Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE ENDICOTT SDI 3-41/K-39 WORKOVER PLAN OBJECTIVES: A rig workover is needed to replace leaking tubing in 3-41/K-39. The Kinley caliper shows 50% of the existing 5-1/2" IPC tubing is rerunnable.. The scope of the work will be as follows: 1. Recover the 9-5/8" packer latch 2. Run Latch/PBR on replacement tbg and sting in pkr. 3. Test completion. TIMING: 3rd Quarter 1994 days plus well to well move with dg Doyon 15 PRE-RIG OPERATIONS 1. RU slick line. Dummy off gas lift mandrels. Pull the WL SSSV. 2. Kill well with 9.3 ppg brine. 3. Set a plug in the tailpipe and test casing and packer to 3500 psi. Pull plug. . RUE line. RIH and cut the tubing in the first full joint of tubing above the latch. Circulate out the IA with 9.3 ppg brine. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If dg move is delayed to more than three days after the well kill, a deeper freeze protect will need to be done. . Dig out the cellar and level the pad. Inspect the wellhead and tree. Function test the LDS's. .R,,IG OPERATIONS , concerningM°bilize DoyOndg moves.15. Review Endicott Simultaneous Operations PlanE (~ ~V ~ [~ . Pull the BPV. Check that the well is dead. Set the TWC. JUL 2 8 1994- . . ND the tree and NU the BOPE. Test the BOPE. (1/2 day) Alaska 0il & Gas Cons. Commission Anchorage Screw in the landing joint. Pull and LD the 5-1/2" tubing to the cut point. (1/2 day) 5. GIH w/overshot and DP. Fish the latch. (1/2 days) NOTE: If latch comes out without problems and threads look good, a latch / PBR assembly will be run & stung into the packer. If the latch looks bad the 9-5/8" packer will be milled. DKC Page 1 July 27, 1994 'ENDICOTT SDI 3-41/K-39 WORKOVER PLAN . , 10. L/D DP that cannot be left in the derrick. (1 day) P/U and run 5-11Z' L-80 IPC completion assembly. (1 day) Latch into packer, space out and test packer to 4000 psi for 30 min. Notify AOGCC of test as this is an injector. Test tubing to 4000 psi. (1/2 day) NE) Bop's NU X-mas tree and test to 5,000 psi. Freeze protect the well. (1 day) Release rig and turn the well over to Production. RECEIVED JUL 2 8 1994 Alaska 0il & Gas Cons. Commission Anchorage DKC Page 2 July 27, 1994 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 10, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ennne L Haas ior Technical Assistant !i JLH Enclosures xc: File 06.10 WELL NAME 3-o3/J-33 3-41/K-39 3-35/L-36 1.29/M.25 3-45/M-39 2~14/0-16 ~.-~ 1-15/P-25 ~" 'G'~ 4-08/P-27 ~-| %-I 2-12/Q-16 °1 - OLo 1-63/T-22 ~."~lt (1 1'-51/V-20 DATE INTERVALS LOG NAME RUN NO 5123/93 134oo'- 13670' 5/15193 132oo'- 13655' 5122193 119oo'-12264' 5~24~93 131 oo'-14o71' 512o/93 29'-11848' 611193 10350'-10578' 6~4~93 1 o35o'-10800' 5114193 1195o'- 12960' 5114/93 1195 o'- 12960' 5/17/93 11700'- 12897' 5/17/93 117oo'- 12897' 5/19/93 13000'-13676' 5/27/93 10000'-10300' 5127193 995o'-1o318' 5126193 121oo'-127oo' 5~26~93 114oo'-12200' 5115~93 113oo'-12500' 5116~93 1235o'-12600' 5118~93 1235o'- 12600' PFC/CCL PRODUC~ LCXT=GING PFK:X3UCTION I..(:XT.~ING PDK - 100 P~TION I. JDC-~ING PRODUC'I'X:~ LOGGING PRODUCTION LOGGING DUAL LATEROLOG - MsFL DLL-MSFL-GR SSTVD LOG CNIJGR 81~GR/CCL PRODI~TION LOGGING P~TION UDC~ING PRODUCTION LOGGING PRODUC~ LOCkING GFI/CCL PFC/CCL PFC/CCL PFC/CCL 1 1 ! 1 1 1 ~ , ! 1 ! ! 1 1 1' : 1 ! ! 1 COMPANY NAME 'ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS SCHI.UM~ SCHU..IVlIgEI::IC.~ ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-51/V-20 tO~t 4/1 9/93 q~.-" ~ 4/22/93 4/22/93 5/3/93 ~.~ 5/14/93 1-55/R-25 5/8/93 2-14/O-16 ~;O'-I~ 4/26/93 2-28/P-19 ~'~.--~L~ 5/2/93 3-29/J-32 g0-' I~l.~ 5/2/93 3-39/J-39 <~/~'1 [(~ 4/30/93 3-41/K-39~,~ ~ 4/24/93 11200'- 12740' 10000'-12721' 10000'-12721' 11300'-12691' 11900'-12694' 12900'-13195' 9200'-10585' 10050'-10335' 12290'-12416' 13930'-14276' 12640'-12648' DIL/SFL/GR CBL CNL/GR/CCL PFC/GR CBL Production Logging Services GR/CCL PFC/GR Production Logging Services PFC/GR Vertilog 1 1 1 1 1 '1 1 1 1 1 1 Schlumberger Atlas Wireline Services Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Services Services Services Services Services Services Services Services Services BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 19, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ~a~n-ne L. Haas- Senior Technical Assistant II JLH Enclosures xc: File 06.10 RECEIVED MAY 2 0 993 - STATE OF ALASKA ALA~r~A OIL AND GAS CONSERVATION COMMISS~,,~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other × I 6. Datum elevation (DF or KB) KBE = 55.3~eet I 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658'SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic 7. Unit or Property name Service ~ Duck Island Unit/Endicott 8. Well number 3-41/K-39 SDI ~ 9. Permit number/approval number 88-126/93-070 10. APl number 50- 029-21878 11. Field/Pool Endicott Oil Pool 13760feet 10459 BKBfeet 13678feet 10401 BKBfeet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 92' 30" Driven 2466' 13 3/8" 3336 c.f. Permafrost 12984' 9 5/8" 575 c.f. Class G Measured depth True ve~ depth BKB 131' 131' 2505' 2503' 13023' 10000' 993 7" 420 c.f. Class G 12767'- 13760 measured 13412'- 13421', 13426'- 13442', 13532'- 13624' 9821'- 1O514' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297' 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6/l/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ^}aska Oil & Gas Gons. Gom~ls~'~ou Anchorago 14. Prior to well operation Subsequent to operation Representative Daily Average production or In]ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 33,214 ~' 0 23,848 '''-''j 0 Tubing Pressure 2015 1495 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended Service/-f.Y',~F-~-~-~ 17. i hereby certify that the foregoing is,true and correct to the best of my knowledge. Form 1~4 Rev 06/15/88 SUBMIT IN DU'PLIC~TE OPERATOR: WELL NAME COMMENTS: coMMENTS: -STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .. Mechanical Integrity Test TYPE PACKER REQ TBG TIME TIME TIME ANNULUS I TVD J CASING TBG TEST CSG TBG TBG TBG START F """~'~"/ ~ '/"/.~' ~,z,' ~.~u-/.... ~,,.5~1['/~,,125°o (,oo ~.~-.-. 2-~o- ~~ ,,/p,,,,,I ' '~- I ,.,, ? ~ -- tr,, ~ , m ~ m . II0o ~50ox~ ~o .. COMMENTS: COMMENTS: COMMENTS: *TUBING INJECTION FLUID: = PRODUCED WATER INJ. ' SALT WATER INJ "MISCIBLE INJ. INJECTION = NOT INJECTING Distribution: odg - Well File c - Operator c - Database c - Tdp Rpt File c - Inspector ANNULAR FLUID: GRADIENT: WELL TEST: DIESEL Inillal , GLYCOL 4 - Year '~ SALT WATER Workover DRILLING MUD Olher OTHER OTHER AOGCC REP SIGNATURE OPERATOR REP SIGNATURE FI-051L3 Rev. 12/93 · . Endicott Production Engineering Department ..... ,QPERATION~ REPORT DATE: 3/19/93 WELL N=: 3-41/K-39 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: PULL PLUGS HOBBS OTIS/JERRY I, DATE/TIME OPERATIONS SbMM'ARY I . 3/17/93 . 0700 TGSM, MIRU ON 3:03' STAND BY FOR STATE INSPECTOR. TO OK 3-41. ... 0900 STATE INSPECTOR oN' SITE. PRESSURE UP WELL. 1015 2500 PSI ON WELLHEAD AND IA FOR 30 MINUTES. HELD'0K. RDMO OTIS FROM 3-03. MIRU ON WELL 3-41. 1100 RIG UP ON 3-41, STAND BY TO 'THAW SWAB 'VALVE ' , 1330 PRESSURE TEST BOP & LUBRICATOR TO 2500 PSI. 1430 RIH WITH 3 1./2 GR & PRONG TO 12639 WLM~.BEAT ON PLUG FOR 1 HOUR. 1700 SHEAR OFF POOH, ADDED WEIGHT. 1820 . RIH WITH 3 1/2 GS TO 12640 WLM, BEAT FOR 40 MIN, POH WITH PLUG. 2000 RIH WITH 5 1/2 GS TO12639 WLM, POH WITH NIPPLE REDUCER. 2200 RIH WITH 4 1/2 GR & PRONG TO 12750 WLM, LATCH'[:D PLUG,POH, GR SHEARED. ,,,, 2300 RIH WITH 4 1/2 GS TO 12750 WLM, BEAT FOR 1 HOUR, SHEARED OFF,POH. 3/18/93 0200 RIG DowN.. SIP=200 lAP=750 CAP=0 , 0900 RIG UP, PRESSURE TEST BOP & LUB. 1015 RIH WITH 4 1/2 GS TO 12745. WLM, BEAT FOR I HOUR, SHEARED OFF, POH. 1300 RIG' UP .125 WIRE. .. 1400 RIH WITH 4 1/2 GS TO 12707 WLM, BEAT FOR 1/2 HOUR, SHEARED OFF, POH 1600 RIH WITH I 5/8 GLOBAL & 3.625 SWADGE TO 12707 WLM,POH~ NO VALVE. 1730 RIH WITH 2.25 LIB, 2.25 TS & 3.50 TS TO 12737 WLM, POH. LIB SHOWS NO VALVE IN PLUG. 1915 RIH'WITH 4 1/2 GS TO 12732 WLM, LATCHED PLUG, GOT 1 HIT@ 1750 LBS. POH. 2100 ON SURFACE WITH PLUG, RIG DOWN. SIP=200 lAP=750 CAP=0 .o~.: ~.. ~^s.,~. v^.v~ ~.o.,.~ w^s .o~ .~cov~..~ ,. ~... 1/2" PLUG. IT IS FLOATING AROUND IN THE TUBING STRING SOMEWHERE. PROBABLY IN A BELLY DOWN MANDREL. ~E~E~V~D APR 2 9 t~99~ ,~taska 0ii & Gas Cons. {;ommissio~, Anchorage BP EXPLORATION March 24, 1993 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ~denior Technical Assistant II JLH Enclosures xc: File 06.10 RECEIVED MAR 2 5 1993' Alaska Oil & Gas Cons. Commissjo, Anchorage BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANYNAME ~.-- I 1'1 -2-12/Q-16 t.-"3/16/93 10116'-10321' v" 3/16/93 9940'- 10409' V' 3/16/93 9940'10409' v 3/16/93 9940'-10409' ~" ["2..~ 3-03/J-33 v"2/20/93 12000'-13742' ,.-2/21/93 12573'-13660' ,~S'"' 1'~'~3'41/K'39 v 3/10/93 0-12780' v'2/28/93 12600'-13650' Repeat Formation Tester Compensated Neutron/Litho-Density Dual Laterolog Micro-SFL SSTVD Log/DLL-MSFL-LDT-CNL-GR Segmented Bond Log/GR/CCL Gamma Ray Log Production Loggin Services PFC/Casing Collar Log Schlumberger Schlumberger Schlumberger Schlumberger Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services Atlas Wireline Services STATE OF ALASKA : ""'"~ ALA~,~, OIL AND GAS CONSERVATION COMMISSar.,,4 ~, APPLICATION FOR SUNDRY APPROVALS I Abandon Suspend Operation Shutdown Re-enter suspended well I Alter casing Repair well Plugging Time extension Stimulate J.~-~"" ' I Pull tubing Variance X Perforate Other ~-~?.I 6. Datum elevation (DF or KB) KBE = 55.3 fee~i 1. Type of Request: Change approved program __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658'SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571' SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539'SNL, 4319' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service RE( E]VED AR 1 9 199 5 A~aska 0il & Gas Cons. C0mm~ss~0~ ;Anchorage 13760 feet 10459 BKB feet Plugs (measured) 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-41/K-39 SD/ 9. Permit number 88-126/9-466 10. APl number 5O - O29 -218 78 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 13678 feet 10401 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~;)~B TrueBv/~ical depth 30" Driven 131' 131' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 9 5/8" 575 c.f. Class G 13023' 10000' 92' 2466' 12984' 993' 7" 420 ct Class G measured 13412'-13421; 13426'- 13442; 13532°- 13624' 12767'- 13760' 9821'- 10514' true vertical (Subsea) 10214'- 10220', 10224'- 10235', 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Attachments 1'4. E~timaied date for commencing operation March 18, 1993 16. If proposal was verbally approved Name of approver Description summary of propOsal X Date approved Detailed operations program __ BOP sketch __ 15. Status of well classification as: Oil __ Gas Suspended __ Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~.~/~ ~. ~ Title SeniorTechnicalAssistantll FOR COMMISSION USE ONLY Condit~ns of approval: NotifY Commission so representative may witness I Approval No..~J'-¢ 70 Plug integrity ~ BOP Test~ Mechanical Integrity Test X · Location clearance Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 3-41/K-39 Variance Tubing to inner annulus communication has been confirmed in well 3-41/K-39 via spinner/temperature profile on 3/10/93. The profile indicates multiple leak points within 10' of the gas lift mandrel at 11578'MD/8869'TVDss. The 9-5/8" casing and packer integrity has been confirmed by setting a plug in the profile at 12641'WLM, above the sliding sleeve, and pressure testing the system (tubing and inner annulus) to 2500 psi. The system holds 2500 psi surface pressure without significant bleed off. A mechanical integrity test with state witness is being arranged for 3/17/93. Well 3-41/K-39 has a simple 5-1/2" carbon steel completion with 6 gas lift mandrels, a sliding sleeve, 9-5/8" permanent HBBP packer and 4-1/2" tailpipe with wireline nipples. There are two options to repair the well. The first is to run a tubing patch across the affected area. This may only be applied if upcoming surveillance tools confirm that damage is isolated to the gas lift mandrel in question. The fall back option, if there is more extensive damage, is to perform a rig workover on this SDI well as soon as the rig is moved back from the MPI, where it is currently drilling development wells. Given the proven integrity of the 9-5/8" intermediate casing string; we respectfully request that the well be allowed to continue injection operations until a remedial workover can be completed in the 3rd or 4th quarter of 1993. Any questions concerning the request may be addressed to Rosemary Hornbrook in Anchorage at 564-4405. RE( EIVED MAR Alaska Oil & Gas Cons. 6ummissio~ Anchorage 2868/prh R.T. ELEV = 55.3' B.F. ELEV= 16.5' MAX. DEV. = 51:15 9200' MD 13-3/8", 68#/!t. L-80, Btrs Csg 9-5/8", 47#/It NT80S XO to NT95HS TOP OF 7' LINER ! 12767' I ,.._ ',,.. 9-5/8", 47#/ft, NT95HS, NSCC I 13023' I ),, PERFORATING SUMMARY Ref. Log: DLL-GR (12-31-88) 13532'-13624' 13412'-13421' 13426'-13442' PBTD ~ 7', 29#/ft, SM-110, I I Btrs-TKC DATE 2-09-89 6-13-89 ~BY ~ COMMENTS LETION I JLH IADD'L PERFS ! I TREE: 6" / 5000 psi / CIW WELLHEAD:r 13-5/8' / 5000 psi / McEVOY SSSV LANDING NIPPLEi OTIS (4.562" I.D.) I 1566' 5-1/2", 17#/It, L-80 Btrs w/I'KC Collars GLM's, CAMCO, BI( Latch NO. TVDSS MD-BKB 6783' 8194' 8869' 9368' 4398' 8450' 10644' 11578' 12239' 1 SLIDING SLEEVE OTIS "XA" 112652, (4.562" I.D.) TIW Latch I (Rt. Hand Release) 12712' 9-5/8' PACKER I TIW (HBBP) (Big Bore) 12714' 4-1/2", 12.6#/ft L-80, TAILPIPE 4-1/2" 'X' NIPPLE I OTIS (3.813" I.D.) 12765' 4-1/2" 'XN' NIPPLE I OTIS (3.725" I.D.) 12806' 4-1/2" WLEG I12848, MAR I 9 t99; AJask,~ Oil & Gas Cons. Com~iss¥ Anchorage ENDICOTT WELL: 3-41 / K-39 AP! NO. 50-029- 21878 COMPLETION DIAGRAM BP EXPLORATION, INC. BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-55/R-2S ~-ZI 7/30/92 8/15/92 2-08/K-16 O~-(/'/ 7/29/92 2-42/P-13 ~'"'1~5'"'7/1 0/92 2-64/U-10 ~e"'"/? 7/29/92 3-21/L-34 $~'"~' 7/11/92 3-27/M-33 3~" ~ 8/3/92 3-41/K-39 ~,.~.,~ 7/16/92 3-45/M-39 3~.$~ 7/1 7/92 13000'-13500' 12900'-13190' 3978'-11170' 11400'-12268' 8800'-9610' 12200'-12846' 11470'-12073' 13350'-13650' 11700'-12650' PUMP-IN-TEMPERATURE SURVEY PFC LOG PRODUCTION LOG/TBG LEAK DETECTION/PRESS/ TEMP/SPIN PRODUCTION PROFILE SURVEY (FLEXSTAK) TEMPERATURE LOG PRODUCTION PROFILE SURVEY (FLEXSTAK) DUAL BURST TDT LOG TDT-P INJECTION PROFILE SURVEY INJECTION PROFILE SURVEY ONE CNE ONE CNE ONE ONE ONE CNE ONE CAMCO ATLAS WIRELINE SERVICES SCHLUMBEI:iC~R CAMCO SCHLUMBE~ CAMCO SCHLUMBERGER CAMCO CAMCO BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevarct P.O. Box 196612 Anct~orage, Alaska 99519-6612 (907) 561-5111 September 6, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reoorts Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells Well Name Date _ 1-21/K-25 8-14-90 1-67/'1'-20 8/12/90 2-26/N- 14 8-12-90 2-36/O-14 7/14-15/90 2-46/Q-15 8-13-90 2-52/S- 14 8-13-90 3-41/K-39 8-11-90 4-18/S-30 - 8-13-90 4-26/0-34 8/11/90 4-42/P-38 8/10/90 4-46/N-39 8/1 2/90 5-01/Sag Delta #7 8/10/90 5-02/Sag Delta #10 8/15/90 If there are any questions regarding this data, please 564-5225. SinCerely, ~anne L. Haas contact Jeanne Haas at RE' 'EIVED SEP I 1 1990 · as~l.0jl.& Gas Cons. uommission CBT 2961'-14592' SCHLUMBERGER 8/28/9O RUN ONE WELL 3-41/K-3~) STATIC TEMPERATURE SURVEY 13166'-13660' CAMCO 8/11/90 RUN ONE FREEZE BACK TEMPERATURE SURVEY 8/11/90 1500'-13660' RUN ONE CAMCO WELL 2-68/S-17 9/3/90 PFC LOG 9800'-11126' RUN ONE ATLAS WELL 3-39/J-39 PERFORATION RECORD 13980'- 14530' SCHLUMBERGER 9/9/90 RUN ONE WELL 4-08/S-30 8/13/90 TEMPERATURE SURVEY 11082'-11330' RUN ONE HALLIBURTON RESERVOIR SERVICES WELL 4-1 ~/P-27 9/10/90 DUAL STATIC SURVEY 13201 '-1 3201' RUN ONE HALLIBURTON RESERVOIR SERVICES WELL 4-26/O-34 8/11/90 TEMPERATURE SURVEY 10874'-11150' RUN ONE HALLIBURTON RESERVOIR SERVICES *GAMMA RAY SURVEY 11600' - 12350' Camco 6/25/9O Run No. 1 *PRODUCTION PROFILE 6/28/90 11700' - 12350' Run No. 1 Camco WELL 3;11/M-:30 6/29/90 *DUAL BURST TDT LOG (TDT-P) 12675' - 13395 Run No. 1 Schlumberger WELL 3-21/L-34 7/2/90,,, *DUAL BURST TDT LOG (TDT-P) 12290' - 12834' Run No 1 Schlumberger WELL 3-27/M-33 5/19/90 *DUAL BURST TDT LOG (TDT-P) 11500' - 12070' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11500' - 12070' Run No. 1 Schlumberger '~ WELL 3-35/L-36 7/!!9,0, *DUAL BURST TDT LOG (TDT-P) 11980' - 12390' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11980' - 12390' Run No. 1 Schlumberger WELL :3-41/K-:39 *TEMPERATURE LOG 12900' - 13650' Camco 5/7-8/9O Run No. 1 5/19/9O 7/1/90 *INJECTION PROFILE TEMP WARM BACK 13200'- 13669' Run No. 1 Camco 6/12-13/90 WELL 4-04/T-26 *RADIO ACTIVE TRACER LOG 13530' - 14027' Run No. 1 Schlumberger AUG -- 2 1990 Alaska 0il & Gas Co.s. (;ommissior~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 24, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: '"~ELL 1-63/T-22 APl No 50 029 21905 Run No. 2 *PRODUCTION PROFILE 12000'-12660' 6/7/89 5 inch log scale cased hole well _ logged by Camco WELL 3-41/K,39 *COLLAR LOG 13300'- 13638' 5 inch log scale APl No 50 029 21878 Run No.1 6/12/89 cased hole well logged by Atlas Wireline Services "'"~WELL 3-01/N-29 APl '50 029 21678 Run No.1 *SPINNER HP PRESSURE TEMPERATURE LOG 12280'- 12730' 4/23/89 5 inch log scale cased hole well logged by Halliburton WELL 2-70/U-15 APl 50 029 21899 Run No.2 *PERFORATING RECORD 11190'-12050' 6/19/89 5 inch log scale cased hole well logged by Schlumberger " ~ WELL 2-68/S-17 APl 50 029 21858 Run No.1 "'---..~*PRESSURE BUILD UP SURVEY 10023'-11200' 3/24/89 no log scale cased hole well "~ PRODUCTION LOG 10600' -11000' 6/11/89 5 inch log scale cased hole well logged by Schlumberger WELL 1-27/P-20 APl 50 029 21693 Run No.1 ~"~*PRODUCTION PROFILE LOG 990o'-10850' 6/27/89 5 inch log scale cased hole well logged by Camco VV. ELL 2-22/L-14 APl 50 029 21931 "'"-'*INJECTION PROFILE LOG 11748'-12100' 6/14/89 5 inch log scale cased hole well logged by Camco Run No. 1 V~ 2-04/M-19 AP! 50 029 21586 Run No.1 TEMPERATURE LOG 10100'-10660' 6/13/89 5 inch log scale cased hole well logged by Camco WELL2-08/K-16 APl 50 029 21676 Run No.1 '""'4*PRODUCTION PROFILE LOG 11700'-12200' 6/9/89 5 inch log scale cased hole well logged by Camco WELL 3-17/J-30 APl 50 029 21946 ""-~*CEMENT EVALUATION LOG 13040'-14004' 7/3/89 5 inch log scale cased hole well '"'""' CEMENT BOND LOG 103040' - 14004' 7/3/89 5 inch log scale cased hole well ~ GAMMA RAY - CCL 13100' - 13700' 7/5/89 5 inch log scale cased hole well logged by Schlumberger Run No. 1 ~2AlaS~ Oil & Gas ~~~-'~Cons. Com~op Anchora,qe WELL 4-50/K-41 APl 50 029 21940 Run No.1 & 2 '"'"-~PERFORATING RECORD '- 13553'-13564' 6/22/89 Run 1 ~...<.5 inch log scale cased hole well PERFORATING RECORD 13260' - 13820' 7/8/89 Run 2 5 inch log scale cased hole well logged by Schlumberger WELL 2-46/Q-15 APl 50 029 21921 Run No.1 ~*PRODUCTION PROFILE 10600'-11000' 6/21/89 2 & 5 inch log scale cased hole well '""*TEMPERATURE SURVEY 10600' - 11100' 6/24 & 25/89 2 inch log scale logged by Otis WELL 3-17/J-30 APl 50 029 21946 Run No.1 ~ *DUAL LATEROLOG MICROSPHERICALLY FOCUSED LOG 13382'-14102' 3/8/89 ~2 & 5 inch log scale open hole well *COMPENSATED SONIC LOG 13382' - 14080' 6/29/89 2 & 5 inch log scale open h01e well ~*DUAL INDUCTION LATEROLOG 13382' - 14105' .6/29/89 2 & 5 inch log scale open hole well ~ *SPECTRAL DENSITY DUAL SPACED NEUTRON LOG 13382' - 14103' 6/29/89 2 & 5 inch log scale open hole well *FORMATION TEST LOG no depths 6/29/89 no log scale open hole well logged by Halliburton Sincerely, GD/Ims File 06.10 (Iii & ~ C0r~ c0mmi~[~ WELL 3-41/K-39 *SPINNER TEMP LOG 12900'-13664' Run 1 OTIS *DIFFERENTAL TEMPERATURE LOG 12900'-13660' Run 1 HALLIBURTON WELL 4-50/K-41 *PACKER COL-LOG 12875'-13622' Run 1 HALLIBURTON *PULSE ECHO CEMENT EVALUATION (PET) LOG 13103'-13927' Run 1 HALLIBURTON WELL 1-05/O-20 '%~*INJECTION PROFILE LOG 10350'-11000' Run 1 CAMCO WELL 3-33/K-37 *TEMPERATURE LOG 12700,-13280' CAMCO Run 1 '~~ WELL 3-39/J-39 *TEMPERATURE LOG 13800'- 14614' CAMCO Run 1 1092/G N D BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 28, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Additional Perforations on Well 3-41/K-39 Dear Mr. Chatterton' Enclosed in duplicate is Form 10-404, Report of Sundry Well Operations, for Endicott Well 3-41/K-39. If there is a need for any additional information, please contact me at 564- 4757. Sincerely, rvoir and Production Engineering JFO/RQM/slk E nclosu res cc: Working Interest Owners 029QM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging . Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571' SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service X 6. Datum elevation (DF or KB) KBE = 55.3 feet 7. Unit or Property name Duck Is/and Unit/Endicott 8. Well number 3-41/K-39 SDI 9. Permit number/approval number 88-126/9-466 10. APl number 50- O29-21878 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 92' Surface 2466' Intermediate 12984' Production Liner 993' Perforation depth: measured 13760 feet 10459 BKB feet 13678feet 10401 BKBfeet Plugs (measured) Junk (measured) Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 131' 131' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 95/8" 575c. f. Class G 13023' 10000' ,, 420 c.f. C/ass G 13412'- 13421' 12767'- 1376O' 13426'- 13442' 9821'- 10514' 13532'- 13624' true vertical (Subsea) 10214'- 10220' 10224'- 10235' 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#~Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L~80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at12714'; 41/2" SSSV at1566' REC~V~ i3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JUL 8,t 8,9 Alaska Oil & Gas Cons..Commis$io~ ~ ~ncJ~orage 14. Prior to well operation Subsequent to operation Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 15,500 0 22,00O 0 Tubing Pressure 1650 1535 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run X ' Oil Gas Suspended Service Water Injector Daily ~ Si ned I/YY/ Y v y~/- -' Form 1/0-4J)4 Rev 06/15/88 I lng is true and correct to the best of my knowledge. Title Manager, Reservoir & Production Engineering SUBMIT IN DUPLICATE EAST DOCK PBA ENDICOTT FIELD PRODUCTION ENGINEERING DEPARTMEN'I' ~83 PO~ PETROLEUM EXPLORATION OPERATIONS REPORT DATE- 6/1 1/8g WELL Ne: :3-41/K-39 TYPE OF OPERATION: BP EXPLORATION REP; SERVICE COMPANY: PULL $SSV, DRIFT 'I'BG,, ADD, PERF$, I .tOFFMANN/BUNDY/BEECROFT OTIS/UNDER, ATLAS WIRELINE/HARPER ii i i ,1, i iiii iiii I ..... DATE/~TIM E OPERATIONS .~IUMMARY I~ i Illllllll' I II I ,, . 6jl 1 /8 9 MIRU otis. RtH/~'flD PULL 5 1/2" OTIS al~l~ 8SS'~' @ 1535'(WLM), POOH. RIH W/3 3/8" DUMMY GUN, TAGGED BTM, Cji) 13~~OH, 6/1 2/89 ADDITIONAL PERF. WORK TO FOLLOW IN THE AM',..__SIP--10O PSI. ~ i i i1 ii i ii ii , i , i 0 6 3 0_ _ 'ATt.AS WIRELINE,,. , , ,. ,. ON LOCATION, 0 7 0 O Ri~ UP ATLA~ NOTI~: BEFORE ~HUT IN, WEI. L WAS TAKIN~i 9,67 MBPD OF .. SEAWATER @ 1295 PSI AND 77 DEG F. VALTEC WAS 60 % OPEN. 0 8 3 0 PRE$$UR"E TES.T LUBRIC~T. OR TO 1.700 PSt. HAD TO REPly, CE 2 O-RINGS. 1 0 2 0 _.R. I=H.._.W/_P..E.._RF. GUN. ' 1 1 40' TIE IN TO 808 CaT OF 1/5/8§: LOGGED FROM 1~i:~'8 TO"1330~'-i~'0SiT]0'~ ,. CCL ~ 13409'{MDBK,.B). THIS PUTS TOP ~;HOT ~ 13412'(MD.EKE). , _1_2 0 0 FIRE GUNS AND. pOOH, ~ ~ 4 o oo~ w/ATLAS. ALL S~:$ F-ii, eD. RIG DOwN A¢~SS'A~.'I URN WELL WATER INJ. SIP=15:0 PSi, PERFORATION INTERVAL' 13412 - 13421 (9') 13426 - 13442 (16') NOTE: WELL PERFORATED W/3 3/8" JUMBO JET GUNS @ 120 DEG ..... PHASING AND. 4 SPF, TOTAL INTERV_AL 8HOT..,=...~.5'... Page BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 July 5, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bo~tQm-Hole Pressure Rep(~rts Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name 1-09/J-18 (Lower) 1-09/J-18 (Upper) 1-09/J-18 (Flowing Gradient) 1-63/T-22 .Da~e 06-07-89 o6-o7-89 06-07-89 o6-o7-89 2-04/M-19 06-13-89 2-14/O-16 (Lower) 2-14/O-16 (Upper) 05-13-89 05-13-89 2- 68/S- 17 06-12-89 3-27/M-33 05-23-89 3-41/K-39 05-25-89 If there are any questions regarding this data, please contact Dave MacDonald at 564-469 7. Sincerely, V' JUL ! "'"' BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 30, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: .Stimulation on Well 3-41/K-39 Dear Mr. Chatterton' Enclosed in duplicate is Form 10-404, Report of Sundry Well Operations, for Endicott Well 3-41/K-39. If there is a need for any additional information, please contact me at 564-4757. ~.J../F. OM~nburg ' i ;rvoir and Production Engineering JFO/RQM' Enclosure: 2 cc: Working Interest Owners RECEIVED o 5 989 Alaska Oil & Gas Cons. Commissbn ,, Anchorage STATE OF ALASKA AL'~$KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2504'SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571' SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 13760feet 10459 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.3 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-41/K-39 SDI 9. Permit number/approval number 88-126/9-199 10. APl number 50- 029-21878 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 13678feet 10401 BKBfeet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2466' 13 3/8" 3336 c.f. Permafrost 2505' 2503' 12984' 9 5/8" 575 c.f. Class G 13023' 10000' 993' 7" 420 c.f. Class G 12767'- 13760' 9821'- 10514' measured 13532'- 13624' true vertical (Subsea) 10297'- 10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' RECEIVED t939 Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 15 0 Tubing Pressure 0 1500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report__ __~_~__r)°f Well Op/e~'ati_ons Oil Gas Suspended Service Water Injector 17.1 hereb~e~ that,~/~, r,p'/g/oin~is true and correct to the best of my knowledge. Signed Form 10-~R~/~)6/:1/5'~8 Title Manager, Reservoir & Production Engineering Date ~ '/''0~1' SUBMIT IN DUPLICATE Justification for Well O_Deration on Endicott Well 3-41/K-39. STIMULATION Well 3-41/K-39 is slated for subzone 2A water injection. The well is structurally Iow such that much of subzone 2A is in the tarmat. The top of the subzone is at 10300 feet TVD, the level at which tar is projected in this area of the field. The well was originally perforated with drillpipe conveyed guns, from 13532'-13624' M.D. (92'), and completed with 5-1/2" tubing. The well failed to produce fluids to surface upon completion, and was prepared for water injection into the perforated interval, according to the original plan. An initial injection attempt was made on February 24/25, 1989 using the Endicott Facility pumps. The wellhead injection pressure reached 2800 psi, with no indication of fluid displacement into the well. Downhole pressure during this operation was estimated at 6280 psi, for a pressure gradient of .61 psi/ff. On February 25, 1989, the well was freeze protected with 41 bbls of diesel, which was injected at a wellhead pressure of 4450 psi, during 92 minutes. The downhole pressure during this operation was estimated at 7850 psi, for a pressure gradient of .76 psi/ff. At this time, we recommend that a stimulation be performed on the well to establish injection through the tarmat and into subzone 2A. Once injection into the well is established, it is expected that the well will be operated with injection pressures above the fracture gradient, in order to maintain water displacement into the formation. RECEIVED ~laska 0il & Gas Cons. Commission Anchorage WELL ~-41/K-;~9 MUD ACID TREATMENT JOB OBJECTIVES To establish injectivity into subzone 2A. Targeted perfs for the acid treatment are from 13535-13542 and 13548-13562 MDBRT. This 21 ft interval is the lowest tar saturation relative to the overall interval and stands the best chance for injectivity. PRE-TREATMENT 1) Verify that there is no communication history between the tubing and the inner annulus 2) Pull SSSV. Make a drift run for expected CTU nozzle diameter. 3) Make contact with Chemlink (Buck Houchin @ 659- 8367) to perform a flowback analyses (if necessary) on wellhead samples. Be prepared to provide them with produced fluids, samples of treatment fluids, and flowback samples as requested by them. TREATMENT 1) Mix or obtain the following fluids (see attached treatment fluid summary) · a) 3150 gallon b) 525 gallon c) 1050 gallon d) 2100 gallon e) 4200 gallon f) +/- 120 bbls Artic diesel pre-flush Artic diesel overflush RECEIVED 10% HC1 9% HC1/3% HF ;][1~ 0 5 l~ 3% NH4C1 brine Alaska 0il & Ilas Cons. Diesel , gnch0rage Note- filter all treatment fluids that will enter the perfs to 3 microns on the fly. 2) Shut-in the well at the wing valve and flow control valve. 3) Rig up a CTU, pump van, and associated transports. Notify the service company to have a nitrogen truck available for callout if necessary. Assure BOP stack has a pump in sub rigged up. Rig up chicksan line from the CTU pump-in sub to the swab valve at well 3-39/J-39. Shut-in well 3-39/J-39 at the master valve and line out to be available to backflow well 3-41/K-39 if necessary. 4) Attach a large O.D. swirl patterned nozzle and a tubing end locater for a 4 1/2" tailpipe to the CTU. Run double check valves on CTU. Install a fusable cap to the SSV. Ensure a check valve is installed between the pumper and the CTU. 5) Pressure test all iron and BOPS to 4500 psig. 6) Assure digital chart recorder is calibrated and working proper. diesel only as necessary to maintain CT pressure. RIH pumping 7) Tie-in to tubing tail and correct CTU depths to get nozzle on depth with perforations. Note correction in telex. 7) Pump the treatment down the CT in the sequence listed below at a maximum rate within a maximum operating wellhead and CTU pressure of 4000 psig. Once initial leading edge of treatment is at the perfs, begin reciprocating from 13535- 13562 MDBRT at 10-15 fpm. Note comments on chart recorder as specific treatment fluids hit perfs. a) b) c) d) e) f) 75 bbls Artic diesel pre-flush 25 bbls 10% HC1 50 bbls 9%/3% HF Mud Acid 100 bbls 3% NH4C1 brine overflush 12.5 bbls Artic diesel overflush Displace liquids from CT with diesel List all treatment pressures, rates, cumulatives, and comments on job summary telex. 8) If there is an obvious improvement in the injectivity of the well at this point, prepare to open up the well to evaluate injection rate. POH with coiled tubing. 9) Note- If injection is attempted down the production tubing, make sure that diesel is pumped down the coiled tubing to minimize the differential across the coiled tubing and prevent collapse. 1 0) Assuming that the well will inject acceptably, POH with the CT and rig down. Resume injection into the well at a maximum rate. Pump diesel as necessary while POH to maintain CT pressure. Rig down pumper and acid transports. 1 1 ) If the well will not take an acceptable amount of water, stop the coiled tubing at approximately 2000 ft while POH. Make arrangements to immediately flow back well utilizing nitrogen to establish inflow. Have a nitrogen pumper and supplemental transport available. 12) Have the flowline for well 3-39/J-39 lined up to the high flow test separator. Notify the Production Supervisor that the mud acid is going to be flowed back to the plant so he can increase emulsion breaker concentrations to minimize the impact once the acid arrives at the plant. 13) With the well lined up open to flow and the production choke wide open, begin pumping nitrogen at 2000 ft at 1000 scf/min. Once nitrogen discharges out of nozzle, RIH with coiled tubing. 14) Increase nitrogen as necessary to maximize liquid cleanup and recovery. Monitor liquid volumes recovered through separator to predict when bottoms up will occur. 15) Sample as requested by Chemlink. 1 6) Stop CT nozzle at 13500 ft MDBRT and continue to nitrogen lift. Optimize nitrogen pumped to maximize liquid recovery. Estimated optimum gas/liquid ratio will be 1500-2000 scf/bbl. 17) Continue to lift until 2 tubing volumes, approximately 600 bbls, is recovered or until there is no more nitrogen left in the transport. 1 8) Attain 1 quart samples at the wellhead to determine production liquids coming back. 1 9) Once the nitrogen lift is near completion, start the CT out of the hole. nitrogen rates in increments. Reduce 20) Rig down CTU, pumper, and transport. 21) Resume injection. Monitor for improvements from the initial attempt to inject. Even if injection is restricted continue to leave well on injection to assure any remaining acid not flowed from the tubing is displaced from the tubulars and back away from the near wellbore. POST TREATMENT 1 ) Have Chemlink analyze flowback samples. Cons. Oommiss'~n .~ch0tage TREATMENT FLUIDS SUMMARY ARTIC DIESEL PREFLUSH VOLUME- 75 BBLS 1) 2) Provide a source sample of the diesel to Chemlink Add the following Chemlink products to the diesel. vary dependent on test results: a) 5% SS8660 mutual solvent b) 1% SH8072 demulsifier Concentrations may ARTIC DIESEL OVERFLUSH VOLUME- 12.5 BBLS 1) 2) Provide a source sample of the diesel to Chemlink Add approximately 5% SS8660 mutual solvent (dependent on test results) to the diesel. 10% HCL VOLUME- 25 BBLS 1 ) Using the API RP 42 emulsion testing procedures, test for emulsion and sludging tendencies. Tests should be done with a wellhead liquid sample if attainable. In the case of well 3-41/K-39, no sample can be attained and no adjacent well would provide a representative sample. Hence, determination of final additives of demulsifier/anti-sludge and iron sequestrant will be to the discretion of the field engineer based on discussion with the service company. Additive volumes should be determined based on a worst case scenario and determined based on historical lab results to date. Reservoir fluids within the treatment are heavy oil tar and produced water. Tests should include 5000 ppm ferric ion. 2) Prepare the 25 BBLS of 10% HCL with the following additives: Additive Dowell Halliburton BJ Titan Inhibitor Surfactant Iron Reducer Non-emulsifier Anti-sludge 0.6% A-250 0.6% HAI- 85 0.6% Ci-25 0.2% F75N 0.2-0.5 % Losurf 300* 0.2-0.6 % NE 18/41' 1.05#/BBL L-58 1.9#/BBL Fercheck A 1.05#/BBL Ferotrol 210 0.0-1.0% W-54' N/A 0.0-0.2% MS-10* 0.0-1.0% w-35' 0.0-1.2% AS-5* N/A *Concentrations determined from emulsion/sludge testing Acceptable acid concentration is 9.0-11.0 %. Iron content should not exceed 350 PPM. 9% HC1 / 3% HF MUD ACID VOLUME 50 BBLS 1) Use the API RP 42 emulsion/sludge testing guidelines and procedures using a wellhead fluids sample and live and spent 9/3 I-IF acid with additives at 180 deg F. If a sample can not be attained as is the case with 3-41/K-39, estimate a conser- vative acid system for a worst case condition based on vendor recommendations. For tests, add 5000 ppm ferric ion to simulate a worst case situation. 2) Prepare a 9/3 % HF mud acid system as follows: Additive Inhibitor Surfactant Iron Reducer Non-emulsifier Anti-sludge Dowell 1.0% A-166 20#/1000gal A-153 0.2% F-75N / NE41* 1.05#/BBL L-58 Halliburton BJ 0.9% HAI-85 1.0% CI-25 30#/1000gal A 0.2-0.5% Losurf 300* 0.2-0.6% NE18 1.9#/BBLFercheck A 0.0-1.0 W-54' N/A 0.0-1.0% W-35' 0.0-1.2% AS-5* 1.05#/BBL Ferrotrol 210 0.0-0.2% MS 10' N/A *Concentrations dictated by results of emulsion/sludge tests. In the case for 3-41/k-39 conservative best estimates will need to be made due to no available sample. Acceptable concentrations for acids: HF 2.5-3.5% HF + HC1 11.0.13.0 % Iron content should not exceed 350 PPM. 3% NH4C1 BRINE OVERFLUSH VOLUME 100 BBLS 1 ) Prepare a 3% NH4C1 brine solution and add the following: Additive Volume Dowell Halliburton BJ Titan Surfactant 0.2% F-75N Losurf 300 Inflo 45 MAY 15 '89 17:55 EAST DOCK PBA I DEPARTMENT I IIIIII. ' ' - II [ [ BRITISH PETROLEUM EXPLORATION $)_pERATION8 REPORT DATE: 5112189 WELL NU: 3-41/K-39 TYPE OF OPERATION: ML~AC~A~ BP EXPLORATION REP: ALLAN SERVICE COMPANY: ACT/BJ 5/12/89 O700 RIG UP OTIs ~ND PULL S$SV. DRIFT TUBING TO 13650' WLM, WITIt 2,5" DRIFT. .... ~5/13/89 0700 RiG.'"..~._..A..~.._&N..D.._B_Ji'":: ............. ' ......... ' ......... 0800 ........ WOT. WArt ON ORF_~SE TRUCK TO ,,C-~. S~- ~ VALVES. ' ........ 0930 FLANGE UP INYECTOR HEAD AND BOPS TO TREE, INCLUDING A pUMp IN SUB. RIG UP TUBINO END LOCATOR AND 2,5" SWIRL PATTERN NO2ZLE. RIG UP DOUBLE CHECK VALVES. $1WHP=625 PSIG IAP=0 P$IO OAP=125 P~IO INSTALL FUSABLE CAP ON ...... ..s,$v. ......... ~ o00 s,~,~tv M~ndO-Xt, m JOB OV~VmW~ ' lois ' gRESSUP, E TE~T C'Om. P~PtNO, WELLHEAD OONNECTIO~$ At,~ ~O~S TO 4500 PSIO.,....I~L CO~L WITlt DmSFaL, , ........ ~ O30 ZF. RO ~ocrrAo~. COUNT~ AT SWAB VALVE FOR TIE ~N. Srw~P--4oo Pa_!G ~AP~- 0 PSIO ... ..... GAP=- 12S PS~G..... .... NOTE: MONITOR AND BLEED 1AP AND GAP AS REQUIREI) I)URING TREATMENT, ................. : ,.~;: ~ ,, ,~. ~05.s .. ~m..w..tt.~_.crv, ...... ~r,, . '""~"' 1320 WHBN THROUGH TA1LPIPE, PULL UP ON CTU TO TUBING TAIL AT / ....... 12848' MDBKB. ~ IN CTIJ AND CORRECT ODOMETER. CORRECTEDt +44 bEET. NOZZLB I$ 4 ~ BELOW TUBING F.31D LOCATOR. "' $IWHP=400 PSIG ., IAP= 0 PSI¢3 OAPE-.,,,.,12J , ....... TR~&__T_M_E_NT_F_LUII), INCLUI)INO DIE$.E,.L., 1320 BEGIN PUMPING TREATMENT PUMPING AT A MAXIMUM R^TE WITH 4000 PSI SURFACE PRE$$U]~ LIMITATION, C~3M PRESSURB TIME BBL RATE CTU WH FLUID/REMARKS 1334 5 .85 2550 900 DIESEL PREFLUSH 1318 10 1.I 4000 1800 " 1344 15 ,75 4050 2700 " 1350 20 .65 4050 3000 " 1359 25 .~g 4000 3000 HOT DIF_.SEL I 60 DF, GFAT THE PERFS ....... BEOIN RF. CIPROC~TiNG CTI)~I~OM 13562-13535rMDBKB'"/~"A RATE OF 10 - 15 FPM. 1410 S0 .3S 4000 3500 " 1425 35 .~5 4000 3{;00 " 1445 40 ,25 4000 3650 " 1507 45 .22 4100 3800 " 1530 50 .20 4100 38~$ " SS DID NOT PUM ' 60 " 65 " 70 " ............... ~ HAY 15 '89 17:56 DATE: $11218~ ~ELL N**. :~-41/K-:~9 TYPE OF OPERATION: MUD ACID TREATMENT ..... ~530-~"¢-~s .20 41oo 3s5o HCL l/,CrO C~ 1559 80 .20 4200 4125 " 1662 85 .24 4200 4200 " 1642 90 .25 4200 4300 " 1702 95 ,25 4200 4650 " 1720 100 ,35 4200 4200 10 % HCL AT THIB FERP$, START PUMPING 50 BBL OF 9%/3% HF 1724 ,105 ~.7~ 4000 4000 " 1732 110 .81 4000 4000 " 1740 ! 15 .68 4080 4000 " 1751 120 ..55 4100 4200_ " 1757 '125 .65 4150 4050 9 %/3% HF AT TH£ PERFS 1804 130 ,85 4100 3250 " 1810 135 .90 4100 2950 ,, " 1815 140 .95 4150 2800 " 1820 -145 .95 3700 2550 " 1825 150 ,95 4150 2550 START PUMPINO100BBLS OF 3% NH4CL OVERFLUSIt 1834 160 .99 4150 2550 " 1843 170 .99 4150 2550 " 1848 175 ..94 4100 2600 3%NH4CLATTHI~P£RFS 1854 180 .90 4t00 2700 *' 1905 190 .96 4100 2450 " 1917 200 ,90 4200 2650 " 1928 210 .90 4100 2675 ' " 1940 220 .90 4200 2800 " 1953 230 .90 4100 2700 " 2002 240 ,90 4100 2700 " 2012 250 ,90 4100 2675 START PUMPING 25 BBLS OF DIF~EL DISPLACEMENT 2020 260 .85 4150 2650 " 2033 270 .60 3250 2300 " NOTF.~: 2~ ]~BL~ OF HF, A~D DIF~ PREFLUSH WERE NOT PUMPED BI,CAUSE PRF~$URF.~ INCREASED WHILE RATE D~F_,D, IT APPF. ARED THAT TI~ DIF~EL WAS OF NO BF.,N~FIT AND MAY IN FACt BEEN DETRIMENTAL. AT SEVI~RAL POINTS DURING THI/PUMPING OF THE DIESEL I:LkTI~ WENT TO ZERO AND PRF.,SSUI~ WAS INCREASED TO ALLOW THE STIMULATION TO CONTINU~. BENEFITS IN TERMS OF INCREASED RATF~ AND LOWER PUMP/WiiLL~AD PRKgSURE5 WER~ OBSERVED WITEN BOTH THE 10% HCL AND MUD ACID HiT THE PERFS. THE RATE AND PRF,$$UR~ BF, NF,.FIT$ $TABILIZED AFrER A MINIMUM AMOUNT OF FLUID WAS IN CONTACT W~TH THE FORMATION. FUTURE PROGRAM ACID VOLUlVlE$ SHOULD CONSIDER THB 1~~~ OA_..mED. 2o4"--"'--"~ ...... P0tt WITH C'I~. OP~t4 x~m w~u. R4DICATION WAS THAT Z]~O/NF.~LIOIBL~ FLOW WAS OCCURRING. FLOW MET]~ ACCURACY QUF~TIONABLK DESCI$SION TO NITROGEN ~-r CLeAt4 OUT W~L WAS .... ~-~-~ CALL OUT NITROGEN UNIT AND TRANSPORT WHICH was ON STAND BY. NOTIFY' CH~N~ THAT FLOWBACK ANALYSIS WILL BE 5/!4/~' ~400 RIG UP CHICKSAN FROM P~llV~ IN SUB Ol~-:~'-41-TO PUMP IN CAP ON 3-39 AND TEST TO 3000 PSI. THIS WILL ALLOW FLOW BACK FROM TO ENTER THI~ T~ PHASE FLOWLINI~ OF WI~LL ~-39 WITH FLUID RETURNED THROUGH TIlE HIGH FLOW SEPERATOR. EMULSION BRF, AKER INCR~A~ BEFORi~ ~ TREATMENT ENTERED THE FACILITIES .... ~-~ 'JUt{, o 515s9 &iaska Oil 8, 6as Cons. Commission Anchorage DATE: 5112/89 WELL N*: ~.41/K-39 TYPE OF OPERATION: MUD ACID TREATMENT '~'401 R/il WITH CT0-'~' 2000'~ START pUMPING' NITRG~i~ AT 1000 $Ci:M. UNLO^O Ttm ~ ~ C'rU Rtn~S m~O ~Sm' ~~. ~n~ N2~ N2~SS WHP ~W TI~ 2000' ~ooo ~2~5 soo 2~ 0030 ~000' 10o0 17~o 400 75 0050 ~ooo' ~ooo ~7oo ~oo ~4~ o ~ ~o sooo' ~ooo ~Tso ~oo ~7 o~zo 6000' 1000 1750 400 253 0200 7000' 1000 2050 350 300 0208 SO00' 1000 2~50 350 }09 0220 9ooo' ~ooo 2~o ~o ~s~ ~oooo' ~ooo ~6oo ~o a~s o~44 ~ooo' ~ooo 2800 ~o ~3 0=56 12000' 1000 3000 3SO 450 0~08 ~j~' -~boo '" ~'bo "-~-So 4~: o~ 13500' ~000 ........ ~00 3~0 sOO 0326 ...... ~N~M~z~ N2 U$AOE ~D_ M~M~ ~Q~ACK ....... 1000 3250 350 8106 2116 5~5 0330 1250 3400 3~0 5443 2166 628 0~00 1250 3400 ~00 6S89 1941 741 0430 1250 3400 350 5927 ~000 890 0500 1250 3400 ~50 5435 1794 994 0530 1280 ~400 350 6124 2104 1125 0600 i~50 3400 350 6016 1879 1256 0630 1250 3500 400 6016 ~100 1359 0700 0 0 450 6593 2100 1500 0735 0 0 225 1901 0 161~ 0~10 ......... 0 S30 ........ mO ~WN ~.. o~,oo P~ ~ o. i.~o., ,R~Pam so~'e ~Ow,~iR. ~t1~/89 1800 .~ INm~ON R~ ~,850 BOWp,, H~ADER p~S~ 2363. PSI ..... ~QRX mO~. C~ ~NK. ~~ u~~ W~ OE S~2/sg. .... BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 30, 1989 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Additional Perforations on Well 3-41/K-39 Dear Mr. Chatterton: Enclosed in triplicate is Form 10-403, Application for Sundry approvals, for Endicott Well 3-41/K-39. If there is a need for any additional information, please contact me at 564-4757. Sincerer/ / F. Oldenburg nager · Reservoir and Production Engineering JFO/RQM: Enclosure' 3 cc: Working Interest Owners STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance Perforate X Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development__ KBE = 55.3 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service X Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 25O4' SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539'SNL, 4319' WEL, Sec. 3, T11N, R17E 3-41/K-39 SDI 9. Permit number 88-126 10. APl number 50- O29-21878 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13760 feet Plugs (measured) true vertical 10459 BKB feet measured 13678 feet Junk (measured) true vertical 10401 BKB feet Length Size Cemented 92' 30" Driven 2466' 13 3/8" 3336 c.f. Permafrost 12984' 9 5/8" 575 c.f. Class G RECEIVED AlaskaLoii a Gas C4~e th Measured depm BKB' AnCnOrE~ 131' 131' 2505' 25O3' 13023' 10000' 993' 7" 420 c.f. Class G 12767'- 13760' measured 13532'- 13624' 9821'-10514' true vertical (Subsea) 10297'-10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6#/Ft. L-80 tailpipe with nipples to 12848' Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Attachments Description summary of proposal y Detailed operations program BOP sketch X 14. Estimated date for commencing operation June 15, 1989 16. If proposal was verbally approved Oil ~ Gas ~ 15. Status of well classification as: Date approved Service Water Injector 17. I 'y _ce~fy t'"'"'"'"'"~3~ f~,~goi~ is true and correct to the best of my knowledge. Suspended Date ~"/' O~ ISigned/J(~1 lC Plug integrity_ BOP Test__ Mechanical Integrity Test__ Title Manager, Reservoir & Production Engineering FOR COMMISSION USE ONLY of approval: Notify Commission so representative may witness Location clearance Subsequent form required 10- ~:;~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL, SIGNED BY ~ nMl~lll: t~ ~IITI-.I ~.vll,-,~ .......... I Approval No. Aporoved CoPY Comm ,ssior~r~~:~- ~ SUBMIT IN TRIPLICATE Justification for Well Ooeration on Endicott Well 3-41/K-39 PERFORATIONS Well 3-41/K-39 is slated for subzone 2A water injection. The well is structurally Iow such that much of subzone 2A is in the tarmat. The top of the subzone is at 10300 feet TVD, the level at which tar is projected in this area of the field. The well was originally perforated with drillpipe conveyed guns, from 13532'-13624' M.D. (92'), and completed with 5-1/2" tubing. The well failed to produce fluids to surface upon completion, and was prepared for water injection into the perforated interval, according to the original plan. An initial injection attempt was made on February 24/25, 1989 using the Endicott Facility pumps. The wellhead injection pressure reached 2800 psi, with no indication of fluid displacement into the well. Downhole pressure during this operation was estimated at 6280 psi, for a pressure gradient of .61 psi/ff. On February 25, 1989, the well was freeze protected with 41 bbls of diesel, which was injected at a wellhead pressure of 4450 psi, during 92 minutes. The downhole pressure during this operation was estimated at 7850 psi, for a pressure gradient of .76 psi/ft. On May 14, 1989, the well begin injection after an HF stimulation was performed on subzone 2A. The has averaged 15 MBW/D at an injection wellhead pressure of 1600 psi. We recommend perforating from 13,412-13,421 and 13,426-13,442 MDBRT to establish injection into subzone 2B. A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforations are added. Once injection into the well is established, it is expected that the well will be operated with injection pressures above the fracture gradient, in order to maintain water displacement into the formation. REC EIVED ( SDI WELL 3-41/K-39 ) i ii ~ ~o1~ N~I ' I~.~ L~. 8~ ~ ~ J ~~,~.,7,~L~ ' ~ ~. 4T~ Z ~ ~ [ ~RFORA~N~ ~MMARY II DAm ~ COMMAS ENOIC0~ WELL: 3~1 I K-3g 2~ J~ ~N APl NO. 50~2~ 21878 COMPL~ION DIAGRAM in BP ~PLORA~ON, INC. :3-4 1/K- :39 LQO T)RTR 'E~flN$O [SK, (EOflNOa [ .ENI] .LQO~ .OUP ]ENO [DUP QL/L?/et La.d6.eI.' OH LOO~ CNL 31-DEC-88 END[COTT CROSS SECT]ON RUN TI:HE 03/t~/99t"/,49~OS ' ~ IlO PRF/FF/CEPi ~4q. (OlTEIo~oo CNL ~ {Dl'l~ell tso In ILII (OlLlteOOt.e~ BULK -- . .;. ~ .~:..~.~. _ - . .:...;...:...:...:...;... - - ,., ~:: :: : : : - . :.. : :, :,, :,, .:, .:._.:.. ' Lt~ '*r:'r.~'~ ·.. "r:'rx::'"r"r":'. ":' '," 53Rt,[ . <3 - m ~4, [ ~_~ -- ~., ....... ; ..... ~--: .... : . ~, ; ~ : =================================L':!i ! i i -'°' -; ii!i~ii!~i!iii:'"~' ~: '~'': i~'''i'''i''~''~''i'~::i:i:i:i::.~ ..:.:. ~zz} :: :::: :::: :::: :~ . ~ :' ... ...... (---::--h~ ~: ,~o ~ .~. ~~.~... ~.~ l:~i .~.,..;....;....; .................... ................... -~. ~ .~ ..:.-,..i ~ ,. .... .. ,'° ~=,. " : ,' ~ ..... !i~ ~ :'""~:' ~"~'"~' '~:':'' ':'"~:":" ::::::: 'i"i" i ~"'i''~' :"' ":'"'~i~ : : ,,i.~ ..... -.: ..... ........ -'.: ..... -' ..... ~ ...... o -': ~: :: :: ::: :: :: :: ::~i::i::: : ':; ; ; ; -° ................ ' :::::t""t::" :~ -= ' .~.i:...h.....<:....! ..... .- -; 813,[ i .......... ~"-:-".~..2_ · _Ker_z~ '~-.::~.:-.~::' : ~ -'"'~ ..... ~ ..... ':: ....... ° - ' i!.~i .~!iii'-!'i-i?~ ~!!~ '.:'i .......... ~. ............. u, - WELL NAME LOG/DATE ZONE TOP M.D. BOT M.D. H TOP TVD BOT TVD SPINNER SPINNER SPINNER SPINNER 3-41/K-39 DIL 2A 13532 13624 92 10297 10362 12/31/88 BASIC SYSTEM MAKEUP BOWEN PACKOFF' HAND PUMP /I ~ GREASe SEAL FLOWLINE FLOWLiNE VALVE GREASE LINE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 8, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Stimulation of Endicott Well 3-41/K-39 Dear Sirs: Enclosed in triplicate is Form 10-403, Application for Sundry approvals, for Endicott Well 3-41/K-39. Justification and a summary of the general program is attached. If you have any questions or comments please contact Quinn Meads at 564-5880. Sincerely, Engineering JO/LRT/Ims Enclosure' 3 cc: Working Interest Owners Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension ~ Stimulate X Change approved program ~ Pull tubing Variance ~ Perforate __ Other ~ 2. Name of Operator 5. Type of Well: BP Exploration (Alaska) Inc. Development x Exploratory 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service -- Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2504' SNL, 650' WEL, Sec. 8, T11N, R17E At top of productive interval 4658' SNL, 4806' WEL, Sec. 3, T11N, R 17E At effective depth 4571'SNL, 4375' WEL, Sec. 3, T11N, R17E At total depth 4539' SNL, 4319' WEL, Sec. 3, T11N, R17E 12. Present well condition summary Total depth: measured 13760 feet Plugs (measured) true vertical 10459 BKB feet 6. Datum elevation (DF or KB) KBE = 55.3 feet 3-41/K-39 SDI 9. Permit number 88-126 10. APl number 50- 029-21878 11. Field/Pool Endicott O# Poo!. Effective depth: measured true vertical 13678 feet 10401 BKB feet Casing Length Size Structural Conductor 92' 30" S u rf ace 2466' 13 3/8" Intermediate 12984' 9 5/8" Production Liner 993' 7" Junk (measured) Cemented Measured depth True vertical depth BKB BKB Driven 131' 131' 3336 c.f. Permafrost 2505' 2503' 575 c.f. C/ass. G 13023' 10000' 420c. f. Class G 12767'- 13760' 9821'- 10514' Perforation depth: measured 13532'- 13624' true vertical (Subsea) 10297'-10362' Tubing (size, grade, and measured depth) 5 1/2" 17#/Ft. L-80 BTRS to 12714'; 4 1/2" 12.6 #/Ft. L-80 tailpipe with nipples to 12848' 'Packers and SSSV (type and measured depth) 9 5/8" Packer at 12714'; 4 1/2" SSSV at 1566' 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch 14. Estimated date for commencing operation April, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended ,e;oregoing is true 17. I here/~Z~// //,// _,~ _~.,~/ and correct to the best of my knowledge. Signed ~'~'/'//~ Title Manager, Reservoir& Production En~lineering Date ,// ~ ' FOR COMMISSION USE ONLY Con(~io~is of approval: Notify Commission so representative may witness / / Plug integrity__ BOP Test Location clearance J Approval No. ~_ ~/Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10-.,, ~.~.0/~ ORIGINAL SIGNED BY .-q~proved Copy Returned . . I.{')NNIE C. SMITH .~ ~ ,~_o~m~ss~oner Date SUBMIT IN TRIPLICATE~,/ Justification for Stimulation of Endicott Well 3-41/K-39 Well 3-41/K-39 is slated for subzone 2A water injection. The well is structurally Iow such that much of subzone 2A is in the tarmat. The top of the subzone is at 10300' TVD (13,352' MD), the level at which tar is projected in this area of the field. The well was originally perforated 92' MD with drillpipe conveyed guns, from 13532'- 13624' MD (10,297'-10,362' TVD), and completed with 5-1/2" tubing. The well failed to produce fluids to surface upon completion, and was prepared for water injection into the perforated interval, according to the original plan. An initial injection attempt was made on February 24/25, 1989 using the Endicott Facility pumps. The wellhead injection pressure reached 2800 psi, with no indication of fluid displacement into the well. Downhole pressure during this operation was estimated at 6280 psi, for a pressure gradient of .61 psi/ff. On February 25, 1989, the well was freeze protected with 41 bbls of diesel, which was injected at a wellhead pressure of 4450 psi, during 92 minutes. The downhole pressure during this operation was estimated at 7850 psi, for a pressure gradient of .76 psi/ff. At this time, we recommend that a stimulation be performed on the well to establish injection through the tarmat into subzone 2A prior to determining the ultimate utility. Once injection into the well is established, it is expected that the well will be operated with injection pressures above the fracture gradient, in order to maintain water displacement into the formation. The program for this stimulation is outlined below. 1. Rig up Coiled Tubing unit and pump van with Acid tanker containing 3600 gallons "PAD" acid. 2. Attach "swirl" nozzle on the CTU and run in the hole to top of the perforations. 3. Start pumping the acid into the well. When the acid hits the formation, begin reciprocating across the perforations. 4. After the acid has been pumped and displaced from the tubing, pull CTU out of hole. 5. Rig up pump van to take water from seawater header or wellhead injection line. Begin injecting seawater into wellhead, monitoring pressures. Initial injection will be the stimulation volume, followed by the full tubing volume of diesel. If the well should lock up during any of the stages, contact Anchorage Engineering. If injection can be established using the pump van, attempt to convert well to injection via the Endicott Facility pumps (2800 psi). 6. Rig down CTU and Pump equipment. General Tubing Acid Wash Program using Coiled Tubing Unit Method. 1. Pull SSSV and isolate SSV with P.E. pump or fusible cap. 2. Check and monitor annulus pressures during job. 3. Rig up coil tubing unit, pumping unit and acid tanker. Ensure check valve is installed between coiled tubing unit and pump van. . Pressure test treating lines, valves, and coiled tubing unit to 4000 psig for 15 minutes. If possible, use warm diesel when testing during winter months. 5. Shut-in well and RIH with coiled tubing pumping diesel at 1/8 to 1/4 bpm with maximum 2000 psig WHP and 4000 psig coiled tubing unit pressure. 6. At top of perforations start pumping acid @ 1/2 bpm with maximum 2000 psig WHP and 4000 psig coiled tubing unit pressure. 7. Pump required volume of acid, containing the following additives, while reciprocating coiled tubing across pedorations: Dowell 15% HCL Halliburton 15% HCL Inhibitor 0.5% A-200 Inhibitor Anti-Sludge 0.4% W-35 Surfactant Mutual Solvent 10.0% U-66 Mutual Solvent 0.3% HAl-50 0.4% Losurf 251 (Cs 251) 5.0% Musol A Note: Obtain a sample of acid from the acid tanker and visually inspect for suspended solids prior to pumping. Retain sample until tubing wash has been satisfactorily completed and a 4-hour maximum rate test has shown the wash to be a success. If the wash is successful, discard sample. However, if 4-hour rate test indicates poor performance, retain sample for analysis. 8. After acid plus additives has been pumped, displace coiled tubing with diesel while POH. 9. Monitor and record on telex all rates, pressures and volumes of pumped fluids. 10. Rig down coiled tubing unit and pumping unit, leaving well shut-in for 4 hours. Then open well to GC as per general well start-up procedures. 11. Obtain 4-hour maximum rate test on well as soon as a stable production rate has been reached. ~ ii ! II I t BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 13, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well 3-41/K-39 SDI (Endicott) Enclosed, in duplicate, is form 10-407, our Report of Well Completion for the above-named well. This information reflects the current condition and status of the well. Also enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys. The open hole logs were sent under separate cover on January 17, 1989. Yours, very truly, Endicott Drilling Engineering Supervisor JGV/KTH Enclosures (4) cc: Bill Ross MB 7-1 Endicott WlO's w/4 Well File Oil & Gas Cons. Comraissi,,,;,~. Anchorage 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 [] SUSPI~DED I-I ABANDONED [] SERVICE [] Water Injector 2. Name of Operator 7. Permit Number BP Exploration 88-126 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21878 4. Location of well at surface , ~, 9. Unit or Lease Name 2504' SNL, 650' WEL, SEC. 8, T11N, R17E '".'i .IIX;)CA't~ON~. Duck Island Unit/Endicott i. VErIFIeD 10. Well Number At Top Producing Interval ,,~1'~ ~ 3-41/K-39 SDI 4658' SNL, 4806' WEL, SEC. 3, T11N, R17E At Total Depth ~ ~,l'[~~ 11. Field and Pool :::~ ~--J Endicott Field/Endicott Pool 4538' SNL, 4319' WEL, SEC. 3, T11N, R 17E 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Sedal No. KBE = 55.3 I ADL 47503 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11-08-88 12-31-88 01-08-89I 6'-12' Below feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectiOnal Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13760'MD 10514'TVD 13678'MD 10456'TVD YES [] NO []I 1566 feet MD I 1466' 22. Type Electric or Other Logs Run CE T/CB T/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 13-3/8" 68# N T80 Surface 2505' 17-1/2" 3336 cu fl Permafrost 9-5/8" 47# NT80S Surface 10715' 12-1/4" 9-5/8" 47# NT95H 10715' 13023' 12-1/4" 575 cu fl Class G 7" 29# SM-110 12767' 13760' 8-1/2" 420 cuft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDt PACKER SET (MD) Schlumberger 5"@ 4 spf 5-1/2" 17# 12848' 12724' L-80 MD TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13532'- 13624' 10297'- 10362' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" X 9-5/8" Down Squeeze 13-3/8" x 9-5/8" Annulus with 150 BBLS Dry Crude. 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) .January 6, 1989 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SITF IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ,, FOrm 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS '\..,J-3VIATION TESTS '' NAME Include interval tested, pressure data, all fluids recovered and gravity, · MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ~OP HRZ 12673' "" 9752' PUT RIVER 13015' 9994' (ltkilyariak Missing) 13059' 10024' TOP KEKIKTUK : . · ~.., 31. LIST OF A'I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~///~. ~. EndicettDrilling Engineering Signed/~/~ ~' .t/_~~-'~.i Title Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injectior~ ~or in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT November 8, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Current Operation: Moving rig. Moving rig from slot 4-28 to 3-41. Mud Type: SURVEY WT: VIS' PV: YP: ANGLE DIRECTION TVD SECTION Solids: Temp' COORDINATES. DLS. STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 9, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 930 Day: 1 24- Hour Ftg: 810 Current Operation: Drilling 17 1/2" hole Accept rig on 3-41/K-39 at 0900 hours on 11/8/88. Prepare rig to spud. Mix mud. P/U BHA and spud well at 2130 hours on 11/8/88. Drilling 17 1/2" hole at 930'. Mud Type: Spud ,SURVEY MD WT:8.9 VIS:260 PV: 35 YP: 52 FL: 13.5 Solids: 3 Temp: °F ANGLE DIRECTIQN TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 10, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 2350 Day' 2 24- Hour Ftg: 1,420 Current OPeration: Drilling 17-1/2" hole Drill and survey 17-1/2" hole to 2,350'. Mud Type: Spud WT: 9.3 VIS: 150 PV: 17 SURVEY. MD~ ANGLE DIRECTION TVD YP: 54 FL: 17.6 SECTION. Solids: 5 Temp: °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 11, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 2,515 Day: 3 24- Hour Ftg: Current Operation: Rigging up BOPE Drilled to 17-1/2" hole TD of 2,515'. R/U and ran 61 its of 13-3/8" casing. Mixed and pumped 3,304 sacks of permafrost cement. Bump plug and drain riser. POH and N/D riser. Mud Type: Spud SURVEY MD WT: 9.50 VIS: 58 PV: 8 YP: 38 FL: Solids: 6 Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES DL$. STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 14, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 4,310 Day: 6 72- HourFtg: 1,795 Current Operation: Drilling 12-1/4" hole Drill and survey 12-1/4" to 4,310'. Mud Type: Ligno WT: 9.2 SURVEY MD ANGLE 13 3060' 11.8" 22 4,226' 46.6' VIS: 40 PV: 9 DIRECTION N60.1'E N56. fE TVD 3,053' 4,048' YP: 10 FL: 8.1 .S. ECTION 132 704 Solids: 5 Temp: 77 °F (~OORDINATE$ DLS. N67 Ell4 1.95 N380 E597 3.10 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 15, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 5,590 Day: 7 24- Hour Ftg: 1,280 Current Operation: Drilling 12-1/4" hole Drill and survey 12-1/4" hole to 5,590". Mud Type: Ligno WT: 9.3 SURVEY MD ANGLE 24 4,727 46.8 26 5,316 46.8 VIS: 43 PV: 10 DIRECTION N53.7E N56.1E TVD 4,388 4,796 YP: 11 FL: 7.3 SECTION 1,067 1,488 Solids: 6 Temp: 70 °F COORDINATES DL$. ~/594 £897 .36 N834 £1,248 .40 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 16, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 6,205 Day: 8 24- Hour Ftg: 615 Current Operation: Drilling 12-1/4" hole Drill and survey 12-1/4" hole to 6,205'. Mud Type: Ligno WT: 9.6 SURVEY MD ANGLE 27 5566 49.2 29 5882 49.5 VIS:36 PV:7 DIREqSFIQN N56E N57.9E TVD 4963 5168 YP: 8 FL: 7.7 SECTIQN 1672 1910 Solids: 8 Temp: 86 °F COORDINATES DLS N938 El40 .96 N1069 E1603 .50 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT November 17, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 6,980 Day: 9 24- Hour Ftg: 775 Current Operation: Drilling 12-1/4' hole Drill and survey 12-1/4" hole to 6,980'. Mud Type: Ligno WT: 9.6 SURVEY .MD. ANGLE 31 6,198 48.6 33 6,698 48.8 VIS:36 PV:7 D ,IRE~I'ION, N58.4E N58.E 5375 5,704 YP: 6 FL: 7.8 SECTION 2148 2,523 Solids: 9 Temp: 86 °F COORDINATES DLS N1,193 E1,808 .83 N1,384 E2132 .71 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 18, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 7,985 Day: 10 24- Hour Ftg: 1,005 Current Operation: Drilling 12-1/4" hole Drill and survey 12-1/4" to 7,985'. Mud Type: Ligno WT: 9.8 SURVEY MD. ANGLE 34 7,066 49 36 7,639 49.8 VIS'39 PV:9 DIRECTION N57.5E N58.2E 5,946 6,319 YP: 8 FL: 7.8 SECTION 2,798 3,230 Solids: 9 Temp: 89 °F COORDINATES DLS N1,532 E2,366 .12 N1,765 E2,733 .39 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 21, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 9,870' Day: 13 24- HourFtg: 1,885' Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 9,870'. Mud Type: Ligno SUR ,,VEY, 39 41, 44 8289 8658 9783 WT: 9.8 VIS: 39 PV: 10 ANGLE DIRECTION 52.4 N56.2 50.6 N68.8E 50.8 N68.9E TVD 6730 6957 7662 YP: 10 FL: 7.6 SECTION 8731 4021 4894 Solids: 10 Temp: COORDINATES N2041 E3154 N2171 E3415 N2490 E4230 94 °F DLS 0.68 2.11 0.16 STANDARD ALASKA PRODUCTION Daily Drilling Report .- ENDICOTT November 22, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 10,495' Day: 14 24- Hour Ftg: 625' Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 10,495'. Mud Type: Ligno SURVEy 47 9970 10,351 WT: 9.9 VIS: 37 PV: 10 ANGLE DIRECTION 49.9 N70.4E 47.9 N71E TVD 7782 8031 YP: 7 FL: 6.8 SECTION 5038 5324 Solids: 10 Temp: 96 °F COORDINATES DLS N2540 E4365 0.78 N2637 E4636 0.78 STANDARD ALASKA PRODUCTION Rig: PAA #7 Welt: 3-41/I(-39 (SDI) Daily Drilling Report-- ENDICOTT November 23, 1988 at 0600 hrs AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 10976 Day: 15 24- Hour Ftg: 481 Current Operation: Testing BOPE. Drill and survey 12-1/4" hole to 10,976'. POH for motor. Mud Type: LSND WT: 9.8 VIS:38 PV: 10 SU .RVEY MD ANGLE DIRECTION 48 10540 46.9 N71.5E 50 10918 44.7 N76E 8159 8423 YP: 8 FL: 6.4 SECTION 5462 5729 Solids: 10 Temp: 97 °F COORDINATES DLS N2682 E4768 .56 N2758 E5028 1.17 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT November 28, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 12,075' Day: 20 120- Hour Ftg: 1,099' Current Operation: Tripping. Drill and survey 12-1/4" hole to 12,075'. Mud Type: Ligno ,~URVEY 52 53 56 MD 11288 11474 11986 WT: 10.4 VIS: 37 PV: 11 ANGLE DIRECTION 43.3 N70.4E 42.6 N71.1E 40.8 N72.6E 8690 8826 9209 YP: 17 FL: 1.7 SECTION 5982 6108 6444 Solids: 11 Temp: 108 ~F COORDINATES DLS N2838 E5271 0.06 N2880 E5391 0.46 N2987 E5713 0.29 STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT November 29, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 12,240' Day: 21 24- Hour Ftg: 165' Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 12,240'. Mud Type: Ligno SURVEY. MD 57 12125 WT: 10.3 ANOLE 40.9 VIS: 40 PV: 10 DIRECTION N73.4E TVD 9314 YP: 11 FL: 5.9 SECTION 6534 Solids: 12 Temp' 90 °F COORDINATES DLS N3013 E5800 0.38 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT November 30, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 12,585 Day: 22 24- Hour Ftg: 345' Current Operation: Drilling 12-1/4". Drill and survey 12-1/4" hole to 12,585'. Mud Type: LSND SURVEY MD 61 12500 WT: 10.4 VIS:39 PV: 10 ANGLE DIRECTION 40.4 N75.7E TVD 9598 YP: 11 FL: 6.2 SECTION 6776 Solids: 12 Temp: 100°F COORDINATES DL$ N3080 E6036 1.09 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 1, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,033' Day: 23 24- Hour Ftg: 448' Current Operation: Making short trip. Drill 12-1/4" hole to 13,033'. POH for 9-5/8" casing. Mud Type: Ligno SURVEY MD. 66 12976 WT: 10.4 VIS:36 PV: 10 YP: 10 FL:6 ANGLE DIRECTION .TV.D SECTION 47.7 N78.9E 9742 7095 Solids: 12 Temp: 104 °F COORDINATES DLS N3152 E6355 1.98 STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 2, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: Current Operation: 0600 Depth: 13,033' Day: 24 24- Hour Ftg: Cementing 9-5/8" casing. POH and L/D 12-1/4" BHA. R/U and run casing. Cement 9-5/8" casing. Mud Type: LSND SURVEY MD WT: 10.4 VIS:38 PV: 11 YP: 12 FL:6 ANGLE DIRECTION ~ SECTION Solids: 12 Temp: °F COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -. ENDICOTT December 5, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13067' Day: 27 72- Hour Ftg: 31' Current Operation: Stripping in hole. Finish cementing 9-5/8" casing. Test 9-5/8" casing - ok. Drill float shoe and new hole to 13034'. Clean pits and change over to 9.7 ppg bland mud. RIH with core barrel #1 and cut 30' (recovered 23'). Retrieve core. Observe well flowing while servicing barrel. Record pressures and begin stripping to bottom. Mud Type: BLAND SURVEY MD WT:9.7 VIS:196 PV:51 YP:38 FL:5.6 Solids: 12 Temp: ANQLE DIREGTIQN TVD SECTION COORDINATES 92°F DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 6, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,067' Day: 28 24- Hour Ftg: Current Operation: Tripping. Strip to bottom with drillpipe. Circulate out gas and oil mud. Circulate and condition mud. POH for core barrel #2. Mud Type: Bland SURVEY ,,MD, WT: 9.9 VIS: 109 PV: 55 YP: 9 FL: 3.6 Solids: 12 Temp: ANGLE DIRECTION , ~73rD SECTION COQRDINATES 96~F DLS STANDARD ALASKA PRODUCTION Daily Drilling Report December 7, 1988 -- ENDICOTT at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,130' Day: 29 24- Hour Ftg: 63 Current Operation: Coring. POH. Test BOPE. RIH. Coring mn #2. Mud Type: Bland SURVEY, .MD. WT:9.8 ANGLE VIS: 53 PV: 15 DIRECTION TVD YP: 5 FL: 3.4 SECTION Solids: 12 Temp: 96 °F COORDINATES DL$ STANDARD ALASKA PRODUCTION Daily Drilling RePort -- ENDICOTT December 8, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,161' Day: 30 24- Hour Ftg: 31 Current Operation: RIH for core #4. POH with core #2; RIH with core #3; core jammed at 13,161' (32' of core). POH RIH for core #4. Mud Type: Bland SURVEY MD, WT: 9.9 VIS: 55 PV: 15 YP: 4 FL: 3.9 Solids: 12 Temp: 86 °F ANGLE DIRECTION TVD SECTION COORDINATES. DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 9, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,262' Day: 31 24- Hour Ftg: 101 Current Operation: Tripping. Cut core #4 13,161' to 13,202'. Jammed core barrel after 41'. POH with core #4. Service core barrel and RIH. Cut core #5 from 13,202' to 13,262'. Cut 62'. POH with core #5. Mud Type: Bland SURVEy MD WT: 9.9 VIS: 45 PV: 58 YP: 5 FL: 3.5 Solids: 9 Temp: 92 °F ANQLE DIRE{~YFIQN TVD ~ECTION ,~OORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 12, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,440' Day: 34 72- Hour Ftg: 178' Current Operation: Service core barrel. Cut oriented core to 13,440'. 374.5' total footage cut. Mud Type: Bland SURVEY MD. WT: 9.9 VIS'42 PV:9 ANGLE DIRECTION TVD YP: 5 FL: 6.1 SECTION Solids: 10 Temp: 83 °F (~OORD1NATE$ DL~; STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT December 13, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,499' Day: 35 24- Hour Ftg: 59' Current Operation: Tripping. RIH and cut core #10 from 13,440' to 13,499' (59'). Short trip and CBU. POH with core #10. Mud Type: Bland SURVEY MD WT: 9.9 VIS: 42 PV: 10 YP: 5 FL: 5.6 Solids: 10 Temp: °F ANGLE DIRE~TIQN TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT December 14, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,499' Day: 36 24- Hour Ftg: Current Operation: Circulating and conditioning mud. POH and lay down core #10. Well started flowing, casing pressure 68 psi. Strip in hole. Circ& condition mud. Mud Type: Bland SURVEY MD_ WT: 10.2 VIS' PV: YP: FL: Solids: Temp: °F ANqlLE DIRE~TIQN ,TVD SECTION ~OORDINATES. DL$ STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT December 15, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,537' Day: 37 24- Hour Ftg: 38' Current Operation: Coring. Circulate and condition mud to 10.2 ppg. Service core barrel and RIH. Cutting core #11. Mud Type: Ligno SURVEY MD WT: 10.2 VIS: 48 PV: 13 YP: 4 FL: 6.2 Solids: 13 Temp: 94 °F ANGLE DIRECTION TVD SECTION COORDINATES DLS 1~ .~,1~.. STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-41/K-39 (SDI) Daily Drilling Report -- ENDICOTT December 16, 1988 at 0600 hrs AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,561' Day: 38 24- HourFtg: 62' Current Operation: Working stuck pipe. Cut core #11 to 13,561' (62' of core). CBU and POH. Pipe stuck at 13,482'. Working stuck pipe ~ Mud Type: Bland SURVEY MD WT: 10.3 VIS:41 PV: 12 YP: 3 FL: 6.4 Solids: 13 Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT December 19, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,561' Day: 41 72- Hour Ftg: Current Operation: POH w/HWDP fish. Cut core #11 to 13,561'. Differentially stuck BHA at 13,482' while POH. Backed offDP inside 9-5/8" shoe. Ran fishing string and jarred. Backed off at top of Dailey jars & POH on day 41. 60' core barrel+ 200' BHA fish in hole. Plan to jar on BHA. If can't jar free will plug back and sidetrack to TD. Mud Type: Ligno .SURVEY MD. ' WT: 10.1 VIS'45 PV: 14 YP:4 FL:4.6 Solids: 11 Temp: 78°F ANGLE DIRECTION .TVD SECTIQN COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-41/K-39 (SDI) Daily Drilling Report -- ENDICOTT December 20, 1988 at 0600 hrs AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth:. 13,561' Day: 42 24- Hour Ftg: Current Operation: POH. POH with 3 joints of fish. RIH with fishing tools. Screwed into fish. RIH w/stringshot. Backed off at 13,223'. POH to set cement plug. Mud Type: Ligno .SURVEY MD WT: 10.1 VIS: 44 PV: 14 YP: 4 FL: 4.4 Solids: 11 Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily Drilling Report-- ENDICOTT December 21, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 12,901' Day: 43 24- Hour Ftg: Current Operation: Circulate & condition @ 11,400'. POH. RIH with cementing assembly. Set a balanced cement plug. POH. RIH to 11,400'. Circulate and condition mud. MUd Type: Ligno SURVEY MD WT: 10.1 VIS: 44 PV: 15 YP: 4 FL: 4.2 Solids: 11 Temp: °F ANGLE DIRECTION TVD SECTION COORDINATES. DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 22, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600Depth: 13,023' Day: 44 24 - Hour Ftg: Current Operation: POH. Circulate & condition mud. RIH to 13,020'. Did not tag cement. POH. KIH to 9-5/8" shoe. Circulate out gas cut mud. POH. Mud Type: Ligno SURVEY MD WT: 10.1 VIS:39 PV: 11 YP:4 FL:5.5 Solids: 11 Temp: ANGLE DIRECTIQN TVD SE~FION COQRDINATES 94°F DLS STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 27, 1988 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,064' Day: 49 120- HourFtg: 0' Current Operation: RIH with dYna-drill motor. RIH w/drilling BHA. Wash and ream hole to top of cement plug. POH for motor. RIH. Attempt to sidetrack-unsuccessful. POH. Rig up for cementing. RIH and pump balanced plug. Having hole problems. Circulate cement out of hole. POH and make clean out trip. RIH and pump balanced cement plug. POH. P/U drilling BHA. RIH and tag cement. Clean out to top of finn cement at 13,064'. Circulate and condition hole. POH for motor. P/U Dyna-drill. Mud Type: Ligno SURVEY MD WT: 10.1 VIS:50 PV: 11 YP:7 FL:6.2 Solids:9 Temp: 100°F ANGLE DIRECTION TVD SECTION COORDINATES DLS Rig- PAA #7 Well' 3-41/K-39 (SDI) STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 28, 19,'q,q nt 0600 hfs AFE# 717559 API' 50-029-21878 AFE Amount: Current Amount' Current Operation' 0600 Depth' 13,194' Day: 50 24- Hour Ftg: 130' Wash and ream through dyna-drill run. RIH w/motor. Sidetrack out from cemented portion of well. POH P/U rotary BHA. RIH. Mud Type: Ligno SURVEY MD WT: 10.1 VIS: 54 PV: 18 YP: 10 FL: 5.4 Solids: 9 Temp: 92 °F ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Daily l)rilling Report -- ENDICOTT l')cccn~bcr _), 19~,~ a! 0600 hfs Rig' PAA #7 .~9 (SI)I) \¥c I1' 3-41/K- ~' ( AFE# 717559 Al'l: 5()-()29-21878 AFE Amount: Current Amount: Current Operation: 0600 Depth: 13,584' Day: 51 24- Hour Ftg: 390' RIH to circulate well. Wash and ream dyna-drill run. Drill 8-1/2" hole to 13,584'. POH for wash-out. Mud Type: Ligno SURVEY MD WT: 10.1+ VIS:70 PV:20 YP: 17 FL:4.8 Solids: 11 Temp° ANGLE DIRECTION TVD SECTION COORDINATES 94°F DL$ i/v9 I STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT December 30, 1988 at 0600 hfs Rig: PAA #7 Well: 3-41/1<-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,688' Day: 52 24- Hour Ftg: 104' Current Operation: POH. Drilled 8-1/2" hole to 13,688'. Short trip to shoe. Trip for bit. Wash and ream from 13,463' to 13,688'. Lost 900 psi. POH. Looking for washout. Mud Type: Ligno WT: 10.1+ VIS: 52 PV: 17 ANGLE DIRECTION TVD YP: 10 FL: 5 Solids: 11 Temp: SECTION COORDINATES 94OF DLS~ STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-41/K-39 (SDI) Daily Drilling Report .- ENDICOTT January 3, 1989 at 0600 hrs AFE # 717559 AFE Amount: API: 50-029-21878 Current Amount: 0600 Depth: 13,160' Day: 56 96- Hour Ftg: current Operation: Tripping to clean out liner. Ran open hole Iogs. Stuck logging tools. Fished and retrieved logging tools. Rigged up and ran 7" liner and cemented. RIH to clean out liner. Mud Type: Ligno SURVEY MD WT: 10.2 VIS:60 PV:21 YP: 11 FL:3 Solids: 11 Temp: 92°F ANGLE DIRECTIQN TVD. SE ,Q-'TIQN. C0QRDINA~S DLS, STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-41/K-39 (SDI) Daily Drilling Report-- ENDICOTT January 4, 1989 at 0600 hrs AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 12,787' Day: 57 24- Hour Ftg: Current Operation: Cleaning out liner. RIH and clean out cement inside 9-5/8" casing. POH and PFLI 6" bit. Clean out 10' inside 7" liner and test liner lap-ok. Continue cleaning out liner. Mud Type: Ligno SURVEY MD. WT: 10.3+ VIS:69 PV:24 YP: 17 FL:5.4 Solids: 11 Temp: 82°F ANGLE DIRECTION ~ SECTION .COORDINATES DLS. STANDARD ALASKA PRODUCTION Rig: PAA #? W¢lh 3-41/K-39 (SDI) Daily Drilling Report-- ENDICOTT January 5, 1989 at 0600 hrs AFE # 717559 APl: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,677' Day: 58 24- Hour Ftg: 0' Current Operation: Changing over to brine. Continue cleaning out liner to float collar at 13,678'. Test casing-ok. Clean pits and change over mud to brine. Mud Type: Brine SURVEY MD WT: 9.8 VIS: PV: YP: FL: Solids: Temp: °F ANGLE DIRECTION TVD S..E .CTION COORDINATES DL.S. STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT January 6, 1989 at 0600 hrs Rig: PAA #7 Well: 3-41/K-39 (SDI) AFE # 717559 APl: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,678' Day: 59 24- Hour Ftg: O' Current Operation: Pick up perforating guns. Displace to f'fltered brine. Test liner and lap-ok. Run cased hole logs. P/U perforating guns. Mud Type: Brine WT: 9.8 VIS: PV: YP: FL: Solids: Temp: SURVEY ,MD. ANGLE DIRECTION TVD . SECTION COORDINATES STANDARD ALASKA PRODUCTION Daily Drilling Report -- ENDICOTT January 9, 1989 at 0600 hrs Rig: PA3. #7 Well: 3-41/K-39 (SDI) AFE # 717559 API: 50-029-21878 AFE Amount: Current Amount: 0600 Depth: 13,678' Day: 62 48- Hour Ftg: 0' Current Operation: Rig released. RIH with guns and perforated well. No fluid to surface. RU and ran 5-1/2" robing. Landed robing and secured tree. Set packer and tested-ok. Displace robing w/diesel. Released rig at 2100 hrs. on 1/8/89. Mud Type: Brine Wu' SUR,,VE¥ MD,, WT: VIS: PV: YP: FL: Solids: Temp: · ANGLE D ,.IlgECTION ~ SECTION COORDINATES DLS SUB-$URFA CE DIRECTIONAL SURVEY ~] UIDANCE ~ONTINUOUS r-~OOL Company ,, ~ P E X,,,p L 0 R,A,,I', ! 0 N Well Name 3-41/K-39 SDI (250zJ'. SNL,650, WEL,SEC8.TI'JN,I~17E) Field/Location ,ENDICOTT,. NORTH, . . SLOPE,i ALASKA Jqb Reference No. Date 7310l 6-JAN-89 ~ Computed By: SARBER KOHRING , SCHLU~ESERGER ~: GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 3-~1/K-39 ENDICOTT NORTH SLOPEr ALASKa SURVEY DATE: 06-JAN-S9 .. ,?METHODS OF COMPUTATION ENGINEER: G. SARBER TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOL&TION: LINE~kR VERTICAL SECTION: HORIZ. OIST. PROJECTED ONTO A TARGET AZIMUTH 0= NORTH 54 DEG 40 MIN E~ST ~AGE I BP EXPLORATION 3-41/K-39 SDI ENDICOTT NORTH SLOPE, ALASKA COMPUTATION DATE: OZ-FE~-89 D~TE OF SURVEY: 06-JAN-89 KELLY BUSHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU~-SEA COURSE MEASURED VERTICAL VERTICAL OEVIATION AZIMUTH DEPTH DEPTH DEPTH i)EG MIN DEG MIN 0.00 0.00 -55.30 N 0 0 E 100.00 100.00 44.70 N 83 7 W ZO0.O0 200.00 144.70 19 N 72 22 W 300.00 299.99 244.69 ~! N 53 50 W 400o00 399.99 344.69 O 40 N 39 36 W 500.00 4V9.98 ,44.68 0 39 N 30 30 W 600.00 599.97 544.67 0 40 N 29 53 W 1000.00 999.96 944.66 1100.00 1099.95 1044.65 1200.00 1199.95 1144.65 1300.00 1299.91 1244.61 1400.00 1399.76 1344.46 1500.00 1499.60 1444.30 1600.00 1599.45 1544.15 1100.00 1699.31 1644.01 1800.00 1799.18 1743.88 1900.00 1899.04 1843.74 033 N 53 8 W 0 17 S 70 3l W 0 43 N 32 30 E 2 34 N 49 52 E 3 16 N 55 25 E 3 10 N 58 15 E 3 5 N 62 35 E 2 55 N 64 46 E 2 58 N 65 24 E 3 3 N 66 15 E ZO00.O0 1998.90 1943.60 ZlO0.O0 Z098.75 2043.45 2200.00 2198.59 2143.29 2300.00 2298.42 2243.12 Z400.O0 Z398.24 2342.94 ZEO0.O0 Z498.04 2442.74 2600.00 2597.B1 2542.51 2700.00 2697.44 2542.14 ZBO0.O0 2796.82 2741.52 ZgO0.OO Z895.8B 2840.58 3 6 N 66 30c 3 11 N 58 43 ~ 3 17 N 68 44 E 3 24 N 68 10 E 3 30 N 6a 30 F 335 N 68 56 425 N 63 7 E 5 3~ N 62 27 E 7 8 N 58 5"] E 8 38 N 58 50 E 2~000.00 2994.46 Z9'3 9.16 10 38 3100.00 3092.43 3037.13 12 50 3ZOO.OO 31l~9.13 3133.83 16 31 3300.00 32~3.78 3228.~8 21 12 3400.00 3375.72 3320.42 24 22 3500.00 3466.12 3410.82 26 24 3600.00 3554.61 3499.31 28 56 5700.00 3641.07 3585.77 31 33 3800.00 3724.92 3669.62 34 21 3900.00 3806.0T 3750.T7 37 3 N ~9 8 E N 58 50 c ~6o z~ N 60 21 E N 58 53 E N 57 l E N 55 29 E N 55 15 E N 55 29 E N 55 36 E VERTICAL DOGLEG RECTANGULRR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N O.OO -0.21 0.10 0.16 N 0.31 -0.52 0.31 0.23 N 0.6~ -1.05 0.31 0.67 N 1.4~ -1.54 0.30 1.55 N 2.4'3 -1.72 0.09 2.48 N ?.07 -1.78 0.20 3.48 N 3.6Z -2.11 0.25 4.26 N 4.35 -2.53 0.42 4.60 N 4.98 -2.65 0.18 5.21 N 5.40 0.00 N 0 0 E 0.34 N 62 49 W 0.72 N 71 12 W 1.62 N 65 36 W 2.88 N 57 35 W 3.95 N 51 5 W 5.02 N 46 8 W 6.09 N 45 39 W , 6.78 N 47 16 W 7.51 N 46 2 W -2.89 0.27 5.95 N -3.46 0.37 6.08 N -:3.29 1.36 6.29 N -0.79 2.24 8.22 N 4.50 0.24 11.43 N 10.15 0.65 14.59 ed 15.56 0.13 17.18 N 20.~7 0.52 19.58 N 25.98 0.22 21.73 N 31.23 0.07 23.~8 N 6.01 W 8.46 N 45 17 W 6.70 W 9.04 N 47 47 W 6.62 W 9.13 N 46 29 W 4.77 W 9.51 N 30 '7 W 0.44 W 11.44 N 2 11 W 4.32 E 15.21 N 16 29 E 9.0~ E 1q.43 N 27 51 E 13.82 E 23.97 N 3'5 12 E 18.45 E 28.51 N 40 19 E 23.25 E 33.33 N 44 14 E 36.61 0.29 26.0~ N 42.06 0.31 28.07 N 47.68 0.09 30.11 N 53.53 0.11 32.30 N 59.56 O.1l 34.53 N 65.77 0.33 36.78 N 72.57 0.88 39.73 N 81.10 2.02 43.58 N 92.20 1.65 49.05 N 105.77 1.63 56.01 N 28.18 E 33.24 E 38.50 E 43.93 E 49.55 E 55.36 E 61.48 E 69.10 E 78.7~ E 38.37 N 47 15 E 43.51 N 49 49 E 48.83 N 51 58 E 54.53 N 53 40 E 50.39 N 55 7 E 66.46 N 55 23 E 73.21 N 57 7 E fll.69 N 57 t*5 E 92.~1 N 53 5 E 90.51 F 106.43 N 58 15 E t22.47 1.59 142.38 4.03 167.70 4.25 199.77 5.16 238.91 2.39 281.37 3.17 327.39 2.31 376.94 2.87 430.70 2.73 488.38 2.63 · · 64.64 N 104.90 E 123.22 N 53 Z1 E 74.95 N 122.04 E 143.22 N 59 26 E 87.77 N 143.99 E 158.63 N 58 38 E 103.63 N 171.96 E 200.77 N 5~ 55 E 123.54 N 205.84 E 240.06 N 59 1 E 146.10 N 242.14 E 2~2.80 N 58 53 E 172.16 N 280.72 E 329.31 N 58 28 E 200.71 N 322.03 E 379.45 N 5~ 3 E 231.69 N 366.83 E 433.88 N 57 43 E 264.68 N 415.03 E 492.25 N 57 28 E COMPUTATION DATE: 0Z-FEB-S9 BP EXPLORATION 3-41/K-39 SDI ENDICOTT NURTH SLOPE, ALASKA KELLY DATE BUSHING OF SURVEY ELEVATION: ENGINEER: INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL =DEVIATION AZIMUTH DEPTH DEPTH DEPTH .:D~G;'MIN DEG MEN 4000.00 3884.4Z )829.12 <' N 55 38 5 4100.00 ]959.75 3904.45 N 55 20 E 4ZOO.O0 4031.84 3976.54 N 55 13 E 4300.00 4100.04 4044.14 4 ~3 N 55 17 E 4~,00.00 4167.00 4111.70 47 43 N 55 ~ ~ 4500.00 4234.~4 4179.34 47 15 N 55 31 E ~6OO.O0 4302.64 4247.34 47 2 N 55 36 5 4700.00 4370.98 4'315.58 46 41 N 55 37 ~ 4BO0.O0 4439.85 45B4.56 46 4 N 55 43 E 4900.D0 4509.57 4454.27 45 55 N 55 47 ~ 5000.00 4579.11 4523.81 45 42 N 55 52 E 5100.00 4649.25 4593.95 45 13 N 55 53 E 5200.00 4719.67 4664.37 45 26 N 55 50 E 5300.00 4789.25 4?33.95 46 30 N 55 37 E 5400.00 4851.23 4801.93 47 46 N 55 28 E 5500.00 4923.80 4868.50 /+8 41 N 55 19 E 5600,00 4989.52 4934.22 48 58 N 55 35 E 5700.00 5054.75 4999.45 49 43 N 56 26 E 5800.00 5119.34 5064.04 49 37 N 57 4~ E 5900.00 5184.23 5128.93 49 26 N 58 49 E 6000.00 5249.33 5194.03 49 23 N 59 13 E 6100o00 5314.42 5259.12 49 16 N 59 37 E 6200.00 53~0.02 5324.72 48 43 N 59 29 E 6300.00 5446.27 5390.97 48 30 N 59 39 E 6400.00 55t2.16 5455.36 48 47 N 59 41 E 6500.00 5578.30 5523.00 48 26 N 59 24 E 6600.00 5644.56 5589.26 48 40 N 58 53 E 6700.00 5710.55 5655.25 48 45 N 58 14 E 6800.00 5776.26 5720.96 49 1 N 57 44 E 6900.00 5841.91 5786.61 48 55 N 57 12 E VERTICAL SECTION FEET DOGLEG RECTANGtJLAR SEVERITY NORTH/SOUTH OEG/iO0 FEET 549.73 2.76 299.74 614.64 2.74 ~3~.96 682.99 3.26 ~16.48 755.12 0.71 418.14 ~28.41 0.67 460.38 901.11, 0.38 502.1,7 973.52 0.22 543.59 1045.62 0.29 594.83 111?.22 0.96 625.70 1188.05 0.86 666.04 1259.07 1329.51 1399.68 1470.63 1543.03 1616.69 1~91.07 1765.99 1841.6'7 1917.30 1992.81 2068.44 2143.61 2218.22 2293.17 2367.88 244,".43 2517.14 2592.01 2666.85 2741.50 2815.97 2890.56 2965.02 3039.73 3114.79 3190.02 3265.81 3341.83 3418.03 0.49 706.39 N 0.30 746.35 N 0.52 786.18 N 1.29 826.61 N 1.10 8&8.11 N 0.69 910.48 N 0.58 953.31 N 1.41 995.75 N 1.07 I037.14 N 0.33 1077.02 N PAGE Z 06-J~N-89 55.30 FT G. S~RBER COORDINATES HORIZ. DEPARTURE E~ST/WEST DIST. AZIMUTH FEET FEET DE, G MIN 7000.00 5907.69 585Z.39 48 42 N 96 52 E 7100.00 5973.67 5918.37 48 46 N 57 14 E 7200.00 6039.59 5984.29 48 45 N 57 16 E 7300.00 6105.60 6050.30 48 44 N 57 6 E 7400.00 6171.34 6116.04 49 4 N 57 12 E 7500.00 6236.69 6181.39 49 13 N 57 1~ E 1600.00 6301.83 6246.53 49 35 N 57 10 E 7700.00 6366.29 6310.99 50 4 N 57 ! E 1800.00 64]0.45 6375.15 50 6 N 56 57 ~ 7900.00 6494.39 6439.09 50 20 N 57 3 E 456.31 5 554.33 520.50 E 620.05 5'77.41 E 689.31 637.50 E 762.39 698.59 E ~36.64 759.24 E 910.29 819.74 E 983.60 879.99 ~ 1056.60 939.85 E 1129.08 999.13 E 1200.78 1058.59- E 1272.64 1117.61 E !343.91 1176.39 F 1414.91 1235.75 E 1486.73 1216.21 ? 1560.05 135'7.64 E 1634.67 1419.65 E 1710.03 14~2.45 E 1785.83 1546.59 E 1862.I5 1611.39 E 1938.19 1.)_3 1116.34' N 1676.32 E Z014.02 0.52 1154.64 N 1741.85 E 2089.80 0.46 1192.93 N 1806.91 E 2165.18 0.63 1230.91 N 1811.47 E 2239.99 0.48 1268.90 N 1936.45 E 2315.10 0.43 1306.79 N 2001.13 E 2390.02 0.55 1345.14 N 2055.45 E 2464.85 0.55 ~384.35 N 21~9.55 E 2539.96 0.56 1424.30 N 2193.47 f 2615.33 0.38 1464.86 N 2257.07 E 2690.76 0.56 1505.91 N 2320.23 E 2766.0~ 0.71 1546.80 N 2383.27 E 2841.22 0.45 1587.38 N 2446.58 E 2916.42 0.28 1628.13 N 2509.67 E 2991.53 0.34 1669.02 N 2572.97 E 3066.89 0.13 1709.98 N 2636.62 E 3142.5B 0.64 1751.06 N 2700.41 E 3218.45 0.40 1792.60 N 2764.59 F 3294.90 0.36 1834.37 ~ 28~8.93 E 3371.61 0.25 1876.27 N 2893.40 e: 3448.50 N 57 16 E N 57 4 E N 56 53 E N 56 44 E N 56 36 E N 56 31 E N 56 27 E N 56 23 E N 55 ZO E N 56 18 E N 56 17 E N 56 15 E N 56 14 E N 56 13 5 N 56 11 E N 56 9 E N 56 7 E N 56 6 E N 56 9 E N 56 14 E N 56 20 E N 56 27 E N 56 34 E N 56 39 E N 56 45 E N 56 51E N 56 55 E N 56 58 E N 57 0 E N 57 0 E N 57 0 E N 51 0 E N 51 1 E N 57 1 E N 51 1 E N 57 2 E N 57 2 E N 57 2 E N 57 25 N 51 2 E .) BP EXPLORATION 3-41/K-39 SDI ENDICUTT NORTH SLOPE, ALASKA COMPUTATION D~TE: 02-FE_~-,59 PAGE 3 DATE ~F SURVEY: 06-J4N-89 KELLY ~USHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE IEASURED VERTICAL VERTICAL :DE¥I~TION AZIMUTH DEPTH DEPTH OEPTH {~. GE .'M:~N DEG MIN FEET 8000.00 6558.05 6502.75 N 57 7 E 3494.47 8100.00 6621,53 6566.23 N 57 26 E 3571.10 82[00.00 6684.34 6629.04 N 8400.00 6807.09 6751.79 Zg N 58 46 E 3804.97 8500.00 6868.09 6812.79 Z,) N 65 16 E ~884.02 8900.00 7119.63 7064.33 50 49 9000.00 7182.78 7127.48 50 57 9100.00 7245.55 7190.25 51 8 9200.00 7308.16 7252.86 51 15 9300.00 7370.79 7315.~%9 51 7 9400.00 7433.69 7378.39 51 6 9500.00 7496.68 7441.38 50 49 9600.00 7559.74 7504.44 50 50 9100.00 /'623.10 7567.~0 50 30 9800.{30 7686.90 7631.60 50 11 9900.00 7751.14 7695.R4 49 48 10000.00 7815.91 7760.6! 49 25 10100.00 78~1.25 7825.95 48 58 10200.00 7947.26 7891.96 48 23 10300.00 8014.00 7958.70 47 50 lO~O0.O0 80ql.44 8026.14 47 17 10500.00 ~149.74 8094.4~ 46 42 lO6OO.OO 8Z18.67 8163.37 46 12 10100.00 8298.17 8232.97 45 43 IOBO0.O0 835~.35 8303.06 45 7 10900.00 ~429.30 8374.00 44 27 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH OEG/IOO FEET :EET FEET OEG MIN N 68 57 E 4194.16 N 69 4 E 4271.48 N 69 O E 4349.09 N 69 1 E 4426.84 N 69 11 E 4504.57 N 69 36 E 4582.04 N 69 41 E 4659.41 N 69 48 E 4736.72 N 69 55 E 4813.76 N 70 '3 E 4890.43 N 70 22 E 4966.71 N 70 41 E 5042.50 N 71 3 E 5117.76 N 71 23 E 519Z.38 N 71 40 E 5266.32 N 72 5 E 5339.56 N 72 39 E 5411.94 N 73 lO E 5483.64 N 73 4q E 5554.69 N 74 )0 ~ 5624.94 N 75 46 E 5694.25 11000.00 8501.18 8445.88 43 33 11100.00 8573.92 8518.62 q3 17 llZ00.O0 8646.77 8591.47 43 1Z 11300.00 8719.78 8664.48 43 3 11400.00 8792.91 8737.61 42 47 11500.00 5866.59 8311.!9 42 24 11600.00 8940.64 8~85.34 41 55 11700.00 9015.2~ 8959.9~ 41 26 11800.00 9090.62 9035.32 40 5~ 11900.00 9166.43 9111.13 40 33 N 74 37 E 5762.43 N 70 50 E 5830.40 N 70 55 E 5898.52 N 70 47 E 5966.45 N 70 56 E 6034.26 N 71 5 E 6101.45 N 71 15 E 6168.22 N 71 28 E 6234.32 N 71. 57 E 6299.58 N 72 22 E 6364.24 0.74 0.65 0.72 0.99 3.04 6.09 2.91 0.30 0.68 0.11 1918.20 N 2958.12 E 35Z~.6Z N 57 2 E 1959.93 N 3023.14 E 3602.88 N 57 2 E Z001.86 N 3038.70 E 3680.69 N 57 3 E 2044.17 N 3154.90 E 3759.27 N 57 3 E 2086.54 N 3221.96 E 3838.58 N 57 4 E 2124.22 N 3291.58 E 3917.50 N 57 9 E 2153.18 N 3364.82 E 3994.77 N 57 23 E 2181.01 N 3436.89 E 4070.51 N 57 36 E 2209.10 N 3508.96 E 4146.43 N 57 48 E 2236.99 N 3581.33 E 4222.57 N 58 0 E 0.47 0.Z8 0.65 0.65 0.37 0.25 0.32 0.25 0.27 0.60 2264.76 N 3653.73 E /+298.71 N 58 12 E 2292.56 N 3726.45 E 4375.18 N 58 23 E 2310.52 N 3799.23 E 4451.85 N 58 35 E 2348.35 N 38'72.05 E 4528.53 N 58 45 E 2375.72 N 3944.82 E 4604.95 N 58 56 E 2402.6,5 N 4017.65 E 4681.28 N 59 7 E 2429.55 N 4090.47 E 4757.58 N 59 17 E 2456.16 N 4153.10 E 4833.65 N 59 )7 E 2482.53 N 4235.46 E 4909.38 N 59 37 : 2508.47 N 4307.57 E 4984.74 N 59 47 ~ 0.5'7 0.59 0.55 0.64 1.1Z 0.85 0.70 0.66 0.86 1.25 2533.86' N 4379.40 E 5059.60 N 59 56 E 2558.68 N 4450.92 E 5133.96 N 60 6 E 2582.84 N 4522.05 E 5207.6~ N 60 15 E 2606.44 N 4592.68 E 5280.'14 N 60 25 E 2629.4I N 4662.8~+ E 5353.12 N 60 34 E 2651.5~ N ~732.45 E 5424.64 N 60 44 E 2672.85 N 4801.69 E 5495.49 N 60 53 E 2693.23 N 4870.65 E 5565.67 N 61 3 E 2712.72 N 4939.15 E 5635.07 N 61 13 E 2730.87 N 5007.25 E 5703.53 N 61 23 E 3.33 0.77 0 .Z1 0.15 0.65 0.17 0.63 0.90 0.48 0.42 2747.76 N 5074.69 E 5770.85 N 61 33 E 2768.49 N 5140.0B E 5838.23 N 61 41 E 2791.07 N 5204.75 E 5905.89 N 61 47 E 2813.45 N 5259.32 E 5973.38 N 61 54 E 2835.87 N 5333.73 E 6040.77 N 62 0 E 2857.83 N 5397.63 E 6107.55 N 62 6 E 2879.51 N 5461.29 '5_-6173.92 N 62 11 E 2900.83 N 5524.33 E 6239.63 N 62 17 E 2921.44 N 5586.77 E 6304.51 N 62 23 E 2941.45 N 5648.~% E 6368.79 N 62 29 E BP EXPLORATION 3-41/K-39 SDI ENDICOTT NORTH SLOPE, ALASKA COMPUTATION DATE: 02-FEB-89 PA~E 4 DATE OF SURYEY: 06-JAN-89 KELLY 5USHING ELFVATIDN: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES,FOR EVEN 100 FEET OF ME&SURED DEPTH TRU~ SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH D,EG 'MIN DEG MIN VERTICAL DOGLEG RECTANGULAR C90RDIN&TES HORIZ. DEPARTURE SECTION SEVERITY NgRTH/SOUTH E~ST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN 12000.00 9242.46 9187.16 12100.00 9318.59 9263.29 IZZO0.O0 9394.09 9338.79 5 1Z300.O0 3469.40 9414.10 41 ,. 7 12400.00 9544.76 9489.46 40 59 12500.00 9620.53 9565.2.3 '~40 28 12600.00 9696.6~ 9641.38 40 39 12700.00 9771.71 9'716.41 42 15 12800.00 98~4.52 9789.22 44 1 1Z900.OO 9915.37 9~60.07 45 42 13000.00 9984.12 9928.~Z 47 16 13100.00 10051.60 9996.30 47 8 13Z00.00 10120.63 10065.33 45 29 13300.00 10191.07 10135.77 45 32 13400.00 10260.59 103}05.79 46 13500.00 10329.52 I0274.12 45 54 13600.00 10400.1.1 10344.81 ~4 43 13100.00 10471.25 10415.96 44 38 13760.00 10513.95 10458.65 44 ,38 N 73 3 E 6428.55 N 73 Z? E 6492.65 N 73 3~ E 655'7.44 N 74 19 E 6622.38 N 75 9 E 6587.09 N 76 29 E 6751.13 N 77 59 E 6814.40 N 78 10 E 6~78.69 N 78 24 E 6945.31 N 79 17 E 7013.72 N 79 44 E 7383.90 N 78 45 f 7155.17 N 76 14 E 7225.82 N 76 5 E 7295.38 N 75 51 E 7365.86 N 75 43 E 7436.96 N 75 49 E 7506.44 N 75 3~ E 7575.42 N 75 3~ E 7616.80 0.40 0.89 0 0.60 0.7~ ! . 1 ~' I .36 1 .40 3.56 2 .O7 1.47 3.3~ 1.73 0.85 0.71 2.11 0.17 0.00 0.00 2950.74 N 5710.85 E 6432.72 N 62 35 E 2979.36 N 5772.97 E ~496.44 N 62 42 E 2997.94 N 5835.85 E 6560.86 N 62 48 E 3016.20 N 5899.07 E 6625.44 N 62 55 E 3033.49 N 5962.4~ f 6689.78 N 63 2 E 3049.55 N ~025.73 E 6753.45 N 63 9 E 3063.91 N 608,8.93 E 6816.35 N 63 17 E 3077.53 ~ 6153.62 ~ 6880.28 N 63 25 ~ 3091.47 ~ 6220.73 E ~946.55 N 63 34 E 3105.11 ~ 6289.96 E 7014.65 N 63 43 E 3118.29 N ,5361.3'7 E 7084.54 N 63 53 E 3131.4,~ N 6433.9~ E 7155.57 N 64 2 E 3147.71 N 6504.47 E 7226.08 N 64 10 E 3164.74 N 6573.37 E 7295.53 N 64 17 F 3182.13 N 6643.12 E 7365.93 N 64 24 E 3199.q9 N 6713.33 E 7436.98 N 64 30 F 3217.33 N 67~2.00 E 7506.45 N 6,4 37 E 3234.69 N 6850.09 E 7575.42 N 64 43 E 3245.14 N 6890.93 E 7616.82 N 65 46 E BP EXPLURAT[ON 3-¢1/K-39 ENDICOTT NORTH SLOPE, ALASKA COMPUTATION DATE: OZ-FE8-~9 PAGE 5 DATE gF SUDVEY: 06-J~N-89 KELLY BUSHING ELEVATION: 55.30 FT ENGINEER: G. SARSER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUS-SEA ,COURSE MkASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPIH DEPTH DEPTH 'DE ,MIN DEG MIN VERTICAL DOGLEG RECTANGULAR CgOqDINATES HaRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET DEG/100 FEET FEET FEET OEG MIN 0.00 0.00 -55.30 N 0 0 ~ 0.00 1000.00 999.96944.66 N 53 8 W .-2.89 2000.00 1998.90 1943.60 N 66 30 E 36.61 3000.00 29'94.46 2939.16 ~10 38 N 59 H E 122.47 4000.00 3834.42 3829.12 )9 46' N 55 38 E 549.73 5000.00 4579.11 452'3.81 ' 54 'Z N 5552 E 1259.07 6000.00 52.,9.33 5194.03 49 23 N 59 l~ E 1992.81 ,000.00 5907.69 5852.39 48'hZ~ N 565Z E 2741.50 8000.00 6558.05 6502.75 50 34 9000.00 '~18Z.78 71Z7.48 50 57 N 57 7 E 3.494.47 N 69 4 E 4271.48 N 70 41 E 504Z.50 N 74 37 E 5762.43 N 73 3 E 6428.55 N 79 44 E 7083.90 N 75 38 E 761_6.80 10000.00 7815.91 7760.61 49 25 11000.00 B501.18 8445.88 43 33 12000.UO 9242.46 9187.16 40 25 13000.00 998{.12 9928.82 47 16 13760.00 10513.95 10458.65 ~4 38 0.00 0.27 0.29 ! .59 2.75 0.49 1.23 0.56 0.74 0.47 0.00 N 0.00 E 0.00 N 0 0 E 5.95 N 6.01 W 8.46 N 45 17 W 26.0~+ N 28.1;3 E '38.37 N 47 15 F 64.64 N 104.90 E 123.22 N 58 21 E 299.74 N 466.31 E 554.33 N 57 16 E 706.39 N 1058.59 E 1272.64 N 56 17 E · 1116.34 N 1676.32 E 2014.02 N 56 ZO E 1505.91 N 2320.23 E 2766.08 N 57 0 E 1918.20 N 2958.!2 E '3525.62 N 57 2 E 2264.76 N 3653.73 E 429~.T! N 58 12 0.57 3.33 0 I .47 0.00 2533.86 N 4~79.40 E 5059.60 N 59 56 E 2747.76 N 5074.69 E 5770.85 N 61 33 E 2960.74 N 5710.86 E 6432.72 N 62 35 E 3118.29 N 5361.37 E 7084.54 N 63 53 E 3245.14 N 5890.93 E 7616.82 N 64 46 ~ CDMPUT~TION DATE: 02-FEB-89 BP EXPLORATION 3-41/K-39 SOI ENDICOTT NORTH SLOPE, ALASKA D~TE OF SURVEY: 06-JaN-SO KELLY BUSHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEa DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH D~EG J!MIN DEG MIN -55.30 0.0 0 100.00 200. O0 300.00 ~ 0 4'6 400.00 '0 38 500.00 0 38 600.00 0 37 700. O0 0 24 nJO0.O0 0 26 0.00 0.00 55.30 55.30 155.30 155.30 255.30 255.30 355.31 355.30 '%55.32 455.30 555.32 555.30 655.33 655.30 755.34 755.30 855.34 855.30 N 0 0 E N 67 6 W N 79 6 W N 60 5! W N 47 17 W N 33 32 W N 27 38 W N 44 OW N 61 26 W N 32 13 W 955.34 955.30 900.00 1055.35 1055.30 1000.00 1155.35 1155.30 1100.00 12.55.36 1255.30 1ZO0.O0 1355.46 1355.30 1300.00 1455.63 1455.30 1400.00 1~55.78 1555.30 1500.00 1655.93 1655.30 1600.00 1756.06 1755.30 1700.00 1856.19 1855,30 1800.00 1956.34 1955.30 1900.00 2055.48 2055.30 2000.00 2156.64 2155.30 2100.00 2256.80 2255.30 2200.00 2356.98 2355.30 2300.00 Z457.I7 Z455.30 2400.00 Z557.38 2555.30 2500.00 2657.68 Z655.30 2500.00 2758.19 Z755.30 2700.00 Z858.99 2855.30 2800.00 3 5 N 66 17 E _3 8 N 68 37 E 3 14 N 68 46 E 3 22 N 67 41 E 3 2q N 68 17 E 3 35 N 68 56 E 3 57 N 6] 24 E 4 55 N 63 24 5 629 N 60 10 E 7 50 t,l 59 53 5 2960.19 2955.30 Z900.00 9 54 3062.02 3055.30 3000.00 Il 46 3164.84 3155.30 3100.00 15 16 3269.59 3255.30 3200.00 19 35 3377.61 3355.30 3300.00 23 52 3487.93 3455.30 3400.00 26 3 3600.79 3555.30 3500.00 28 57 3716.80 3655.30 3600.00 32 ~ 3836°99 3755.30 3700.00 35 ZZ ~962.37 3855.30 3800.00 38 44 VERTICAL DOGLEG RECTANGUL&~ COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. aZIMUTH FEET DEG/IO0 FEET FEET FE~T OEG MIN 0.00 0.00 0.00 N 0.00 E -0.07 0.67 O.1Z N 0.14 W -0.36 0.15 0.18 N 0.49 W -0.79 0.51 0.40 N 1.06 ~ -1.36 0.31 1.1~ N 2.05 W -1.66 0.15 2.0,~ N 2.80 W -1.76 0.14 3.03 N 3.3~ W -1.90 0.44 4.0;3 N 4.00 W -2.~8 0.26 4.45 N 4.74 W -2.61 0.24 4.89 N 5.20 W -2.73 0.22 5.6c.. :,1 5-70 W -3.20 0.58 6.13 N 6.44 W -3.57 1.14 6.02 {'4 6.80 W -Z.32 2.04 7.13 N 5.95 W 2.02 0.43 9.98 N 2.49 W 7.66 0.26 13.23 N 2.21 E 13.17 0.05 16.06 N 6.97 E 18.57 0.56 18.57 N 11.76 E 23.71 0.19 20.78 N 16.39 E 28.92 0.09 22.94 N 21.13 E 0.00 N 0 0 E 0.18 N 49 40 W 0.52 N 69 22 W 1.13 N 69 19 W 2.34 N 61 0 W 3.4'7 N 53 53 W 4.54 N 48 8 W ) 5.65 N 44 59 W · 6.50 N 46 47 W 7.14 N 46 46 W 34.25 0.08 25.09' N 26.0l 39.67 0.14 27.20 N 31.01 45.22 0.15 29.2Z N 36.20 50.97 0.20 31.33 N ~1.56 56.95 0.11 33.57 N 47.11 63.09 0.09 35.81 N 52.85 69.44 1.38 38.33 N 58.68 77.25 1.11 41.83 N 65.67 87.26 1.63 46.54 N ?~.51 99.91 1.60 52.98 N 8.02 N 45 15 W 8.89 N 46 24 W 9.08 N 49 27 W 9.28 N 39 49 W 10.29 N 1~+ 0 W 13.41 N 9 30 E 17.51 N 23 27 E ~1.98 N 32 ZO E 26.47 N 38 16 E 31.19 N 42 39 E N 59 5 E 115.34~ Z.50 N 58 53 E 134.44 2.00 N 60 4 E 158.13 2.67 N 60 4~ E 1~9.15 5.44 N 59 1'~ E 229.78 2.82 N 57 21 E 276.08 2.95 N 55 29 E 32 7.77 2.32 N 55 16 E 385.77 2.85 N 55 36 E 451.53 N 55 39 E 526.19 36. I 5 N 46 I E 41.25 N 48 44 E 46.52 N 51 5 E 52.05 N 52 59 E 57.8'5 N 54 31 E 63.84 N 55 52 E 70.09 N 56 51 E 77.85 N 57 30 E 37.85 N 58 0 E ~5.45 E 190.55 N 58 11 E 60.96 N 98.75 E 116.0.5 N 58 18 E 70.81 N 115.22 E 135.24 N 58 25 E 82.98 N 135.67 E 159.03 N 58 32 E 98.42 N 162.68 E 190.14 N 58 49 E 118.83 N 197.97 E 230.89 N 59 1 F 143.19 N 237.65 E 277.46 N 5~ 55 E 172.37 N 281.03 E 329.68 N 58 28 E 205.80 N 329.37 E 388.3R N 58 0 E 243.61 N 384.23 E 454.95 N 57 37 E 286.30 N 446.63 E 530.51 N 57 ZO E BP EXPL1]R .a,T ION 3-41/K-39 SOl ENDICOTT NORTH SLOPE COMPUTATION DATE: 02-FE5-89 PAGE 7 D~TE OF SURVEY: 06-JAN-89 KELLY %USHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE 4EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEC ~IN DEC MIN 4093.99 3955.30 3900.00 N 55 22 4233.88 40'55.30 4000.00 ,! N 55 14 4582.6! 4155.39 4100.00 N 55 22 4550.40 4255.30 4200.00 47 'Zt N 55 35 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST OIST. AZIMUTH FEET DEC/lO0 FEET FEET FEET DEG MIN 610.65 2.70 707.10 3.04 815.71 0.73 923.14 0.23 334.67 N 517.18 E 616.02 N 57 5 E 390.41 N 597.50 E 713.74 N 56 50 E 453.08 N 688.00 E 823.78 N 56 38 E 514.78 N 777.6~ E 932.59 N 56 29 E 4677.12 ~355.30 4300.00 4&~ 47 ~8Z2.18 4455.30 4400.00 45 53 4965.86 4555.30 4500.00 45 52 5108.59 4655.30 4600.00 45 ,11' 5250.95 4755.30 4700.00 45 54 5397.12 4855.30 4800.00 47 44 5547.86 4955.30 4900.00 48 55 5700.86 5055.30 5000.00 49 43 5855.47 5155.30 5100.00 49 32 6009.18 5255.30 5Z00.00 49 23 6162.4]' 5355.30 5300.00 48 55 6313.66 5455.30 5400.00 48 36 6465.31 5555.30 5500.00 48 ~3 6616.26 5655.30 5600.00 48 41 676~3.00 5755.30 5700.00 49 0 6920.38 5855.30 5800.00 48 55 7072.04 5955.30 5900.00 48 46 7223.81 6055.30 6000.00 48 42 7375.53 6155.30 6100.00 48 59 7528.48 6255.30 6200.00 49 16 7682.90 6355.30 6300.00 50 1 ?838.79. 6455.30 6400.00 50 13 7995.66 6555.30 6500.00 50 34 8153.56 6655.3,9 6500.00 51 7 8314.90 6755.30 6700.90 52 17 8479.02 6855.30 6'~00. O0 ~2 23 8640.51 6955.30 6900.00 50 38 8?98.08 7055.30 7000.00 50 49 8956.47 7155.30 7100.00 50 50 9115.53 7255.30 7200.00 51 10 9275.28 7355.30 7300.00 51 15 9454.44 7455.30 7400.90 51 1 9592.98 7555.30 7500.00 50 52 9750.57 ?655.30 7500.00 50 21 9906.44 7755.30 7700.00 49 47 10060.39 7855.30 7800.00 49 9 N 55 36 E 1029.16 N 55 44 E 1132.96 N 55 51 E 1234.89 N 55 53 E 1335.53 N 55 44 E 1435.55 N 55 28 E 1540.93 N 55 Zl E 1652.24 N 56 27 E 1766.53 N 58 29 E 1883.64 N 59 24 ~ 1999.75 N 59 29 E 2115.50 N 59 41 E 222B.43 N 59 31 E 2342.02 N 58 47 E 2454.58 N 57 55 F 2568.00 N 57 6 E 2682.08 N 57 fl E 2795.07 N 57 12 : 2908.29 N 57 10 ~ 3021.40 N 57 I1 E 3136.16 N 57 2 E 3252.82 N 56 56 E 3371.35 N 57 6 E 3491.14 N 57 23 E 3612.34 N 57 31 E 3737.~4 N 63 39 E 3867.39 N 68 59 E 3993.86 N 62 50 E 4115.32 N 69 1 E 4237.81 N 58 59 E 4361.14 N 69 6 E 4495.36 N 69 40 E 4608.75 N 69 48 E 4731.29 N ~9 5~ E 4852.59 N 70 23 E 4971.60 N 70 54 E 5088.01 0.42 0.77 0.22 1.22 1.13 0.32 I .42 0.81 O .99 0.62 0.70 0.39 0.53 0.52 0.36 0.83 0.29 0.44 0.37 0.36 0.26 0.76 0.76 0.89 5.98 1.33 0.69 0.14 0.44 0.29 0.60 0.33 0.46 0.54 0.47 575.41 N 866.24 5 1039.94 N 56 24 E 634.67 N 953.02 E 1145.01 N 56 ZO E 692.67 N 1038.34 E 1248.18 N 56 17 E ~ 749.77 N 1122.66 E 1350.01 N 56 15 E 806.65 N 1206.50 E ~451.32 N 56 14 E 866.90 N 1294.45 E 1557.92 N 56 11 E 930.99 N 13,37.27 E 16'70.70 N 56 8 E 996.12 N 14B2.99 E 1786.48 N 56 6 E 1059.43 N 1582.47 E 1904.36 N 55 11 E 1119.87 N 1692.33 E 2020.97 N 56 ZO E 1178.59 N 1782.58 E 2136.98 N 56 31 E 1236.07 N 18~0.32 E 2250.22 N 56 40 E 1293.61 N 1978.76 E 2364.08 N 56 49 E 1351.48 N Z075.90 E 2477.06 N 56 56 E 1411.42 N 2173.00 E 2591.15 N 56 59 E 1473.21 N 2269.97 E 2706.13 N 57 0 E 1535.40' N 2355.54 E 2820.15 N 57 0 E 1597.07 N 2461.61 E 2934.31 N 57 I E 1659.01 N 2557.43 E 3048.40 N 57 1 E 1721.64 N 2654.75 E 3164.13 N 57 2 E 1785.47 N 2753.~9 E 3281.80 N 57 2 E 1850.63 N 2853.89 E 3401.40 N 57 2 E 1916.37 N 2935.30 E 3522.25 N 57 2 E 1982.30 N 3058.18 E 3644.45 N 57 2 E 3050.51 N 3164.75 E 3771.06 N 57 3 E 2117.15 N 3276.53 E 3901.02 N 57 7 E 2164.30 N 3394.13 E 4025.46 N 57 28 E 3208.56 N 3507.56 E 4144.97 N 5? 48 E 2252.69 N 3622.20 E 4265.56 N 53 7 E 2296.89 N 3737.73 E 43~7.06 N 58 25 E ~341.49 N 3854.04 E 4509.57 N 58 43 E 2385.03 N 3969.96 E 4631.30 N 59 0 E 2427.67 N 4085.35 F 4752.23 N 59 16 E 2469.53 N 4199.74 E ~872.00 N 59 32 E 2510.12 N 4312.20 E 4989.56 N 59 47 E 2548.92 N 4422.63 E 5104.57 N 60 2 E COMPUTATI3N DATE: 02-FE6-89 PAGE BP EXPLORATION 3-41/K-39 SDI ENDICOTT NORTH SLOPE~ ALASKA DATE OF SURVEY: 06-JAN-89 KELLY BUSHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SE~ DEPTH TRUE SUB-SEA IEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE {A~ION AZIMUTH DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES MORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAS'T/WEST DIST. AZIMUTH FEET OEG/iO0 FEET FEET FEET DEG MIN OZl2.1Z 7955.30 7900.00 N 71 25 E 5201.39 0361,.34 9055.30 8000.00 N 71 55 E 5311.31 0508.08 8155.30 8100.00 N 72 41 E 5417.75 0652.81 8255.30 8200.00 ',~/~ N 73 33 E 5521.24 0795.66 8355.30 8300.00 4.5 8~: N 74 28 E 5621.90 0936.34. 8455.30 8400.00 ~44~ 9 N 75 59 E 5719.15 1074.39 8555-30 8500.00 43 171. N 71 31 E 5812.93 1211.70 8655.30 8500.00 43 !0: N 70 54 E 5906.48 1348.63 8755.30 8700.00 43 O' N 70 48 E 5999.47 1484.71 9855.30 8~00.00 42 25 N T1 5 E 6091.21 0.4:9 0.66 0 · 78 0.68 0 1.4? 2.10 0.28 0.30 0.22 2585.73 N 4530.64 E 5216.58 'N 60 17 E 2620.61 N 4635.75 E 5325.20 N 60 31 E 2653.28 N 47'38.06 E 5430.38 N 60 45 E 2683.73 N 4838.14 E 5532.63 N 60 58 E 2711.90 N 4936.18 E ~632.08 N 61 12 E ,2736.99 N 5031.89 E 5728.09 N 61 27 E 2752.77 N 5123.45 E 5820.88 N 61 39 E ) 2793.68 N 5212.32 E 5913.79 N 61 48 E ~ 2824.39 N 5300.67 E 6006.19 N 61 56 E 2854.48 N 538'7.92 E 6097.36 N 62 5 E .1619.67 8955.30 8900.00 41 51 .1753o21 9055.30 9000.00 41 5 .1885.36 9155.30 9100.00 40 35 .2016.86 9255.30 9200.00 40 23 LZ148.56 9355.30 9300.00 40 59 iZ281.28 9455.30 9400.00 41 8 .2413.95 9555.30 9500.00 40 55 L2545o65 9655.30 9600.00 40 24 :Z677.90 9755.30 9700.00 ~! 49 ,Z815o08 9855.30 9800.00 44 25 N 71 15 E 6181.24 N 71 45 E 6269.12 N 72 18 E 6354.80 N 73 8 E 6439.35 N 73 3Z E 6524.06 N 74 9 E 6610.23 N 75 18 E 6696.08 N 77 10 E 6780.05 N 78 11 E 6864.30 N 78 25 6 6955.55 0.36 O .6Z 0.47 0.37 0.40 0.61 0.81 0.87 4.98 1.4~ 2883.72 N 5473.70 E 5186.86 N 6Z 13 E 2911.90 N 5557.59 E 6274.23 N 6Z ZO E 2938.55 N 5639,77 E 6359.41 N 62 28 E 2953.91 N 5'721.31 E 6443.46 N 62 36 E 2988.38 N 5803.45 E 6527.67 N 62 45 E 3012.83 N 5887.21 E 6513.35 N 6Z 53 E 3035.82 N 5971.32 E 6698.72 N 63 3 E 3056.28 N 6054.54 E 6782.20 N 63 1Z E 3074.49 N 6139.14 E 6865.96 N 63 23 E 3093.61 N 6231.05 5 5956.75 N 63 35 E L2957.78 9955.30 9900.00 46 39 L3105.~1 10055.30 'lOOO0.O0 47 4 L3249.14 10155.30 10100.00 45 11 L3392.34 10255.30 10200.00 46 15 L3536.79 10355.30 !0300.00 45 13 L3760.00 10513.95 10458.65 44 38 N 79 34 E 7054.09 N 78 33 E 7159.01 N 76 5 E 7259.94 N 75 53 E 7360.42 N 75 49 E 7462.71 N 75 38 E 7616.80 1.46 3 0.8! 0.70 1.62 0.00 3112.76 '4 6331.01 E 7054.85 N 63 49 E 3132.30 N 6437.84 E 7159.40 N 64 3 E 3156.05 N 6538.28 E 7260.15 N 64 13 E 3180.77 N 6637.74 E 7360.50 N 64 23 E 3206.43 N 6738.77 E 7462.72 N 64 33 E 3245.14 N 6890.93 E 7616.82 N 64 46 E BP EXPLORATION 3-41/K-39 SD! ENDICOTT NORTH SLOPE~ ALASKA MARKER GCT LAST READING PBTD DRILLER*S DEPTH COMPUTATION DATE: DATE DF SURVEY: 06-JAN-89 KELLY BUSHING ELEVATION: 55.30 FT ENGINEER: G. SARBER INTERPOLATE~ VALUES FOR CHOSEN HORIZONS SURFACE LOCATISN : 2504' SNL AN~ 6~0' WEL, SECB, TTll~ R~17 HEASUREO DEPTH BELOW KB 13640.00 13678.00 13760.00 TVD FROM KB SU~-SE A 10428.56 103'~3.26 10455.60 10~00.~0 10513.95 10458.65 RECTaNGULaR COORDINATES NORTH/SCUTH EAST/WEST 3224.23 N 3230.~5 N 3245.14 N 6809.26 E 6835.12 E 6890.93 E BP EXPLORATION 3-41/K-39 SO1 END ICOTT NORTH SLOPE, ALASKA COMPUTATION D~TE: 02-,~EB-89 ? PAGE 10 DATE OF SURVEY: 06-J~N-89 KELLY BUSHING ELEVATION'. 55.30 FT ENGINEER: MARKER *~**~*~:*~* STRAT IGRAPHIC DEPTH K B PBTD 78.00 DRILLER'S DFPTH '~:~ 13760 O0 FINAL WELL LOCATION AT TO: TRU~ SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 13760°00 10513.95 10~58.65 SUMMARY ************ SURFACE LOCATION = 250~' SNL AND 650~ WEL~ SECS~ TTll~ RR17 TVD R~CTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 10q55.60 10400.30 3230.B5 N 6815o12 E 10513o)5 10458.65 3245.14 N 6890.9~ E HORIZONTAL DEPARTURE OIST~NCE ~ZIMUTH FEET DEG MIN 7616.82 N 64 ~6 E SCHLUMBERGER O [ RECT I ONAL' SURVEY COMPANY BP EXPLORATI ON WELL S-4 1/K-S9 SE} I FIELD ENOICOTT COUNTRY USA RUN ONE DATE LOOOED 06 - JAN - 89 REFERENCE 92) l O ] WELL' 3-4'1/K-39 SDI (2504' SNL, 650' WEL, SEC 8, TllN, R17E) HORIZONTAL PROJECTION NORTH 10000 BO00 6000 4000 2000 -2OOO -4000 SoU'rH-6~O -4OOO REF 7:9101 SCRLE : 1/2000 IN/FT 2000 4000 6000 8000 10000 12000 EI:I~ WELL · ~2504' 3-41/K-39 SDI SNL, 650' WEL, SEC 8, TllN, R17E) VERTICAL PROJECTION -4000 -2000 0 0 2000 4000 S000 8000 !0000 !2000 .**,i -,~ .,i ,~ ..... ~...,i ~ ..... i ': ~ i i ~] i ~ ~!i ~ ~ ~ ~ ~ .L.~.. ~ ..... 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L~...~....~ ..... ~-..~...~-~-.{-~-~...~..+.. -' ~-~--~--.4 ~:4-; ..... ~-~-~-4-~-~.-~-~-~-~4--.-.~-.~-~-~+4--+-~-~--.~-~-+-~-~-+-+-- q--+~ ..... +.-+-.+--~ ..... ~+'~'-h-f-'i--~--!-i .... f4'--f-~-l-f'~"~"i-' ~ ~: ; :~ ~ i ~; ~ ] ~ L ~ ;_~_ :.; L.i ~_ ~ ;. L~..._~._~..~-.;-.~-~ ..... ~-~-~-.~ ..... ~-.~-~...~-. ~..~...~.~ ...... ~-~...~...~... -~...~..+-+..+-.+-+..,-. -.~-~.-+..+--}-~+--+--~-- ~T~zE~Z ~ .~ ~ ~..~--~~~-~4-..4.4~-.k~--N-4-4 ....... ~-4-4-4 ...... ~-.N.4... 4-N...~ ....... N..+..~ -.~...~..~.~.~-+.~..+-~ ...... ~..-f.-+-+.~-~.-.~-~.+- PROdECTION ON VERTICRL PLANE 6S. - 24S. SCALED IN VERTICAL DEPTHS HORIZ SCALE = ]/2000 IN/FT DIRECTIONAL SURVEY RECORD AND ANALYSIS Measurements While Drilling COMPANY Standard Alaska Production Company WELL NAME SDI 3-41 / K-39 FIELD/IX~C~ION Endicott / North Slope, Alaska Job Reference Nu~er 15-32249 Logged By: Mark A. Canil ANAl)RILL Date 02 DEC 1988 Computed By: Mark A. Cani] Gas Cons, CO~'ANY SAPC WELL NAME SQl L[CATI~ 1 ~DICOTT LCCATION 2 5 AXIS ~A~iETIC O~LINA~ION 31o10 02-~EC-88 WELL ~]MB~R 41 ~ELL H:AD LO(~TION: LA?(N/-S) 0,00 u~r(E/W) 0,00 TI~ IN POINT(TIP) : ~SURED Q~F~H 0,00 T~UE V:RT DEPTH 0o00 ~NCLI?~TION 0,00 AZIML~H 0,00 LATITUDE(N/-S) 0.00 ~£PARTIJR£(~-W) 0,00 AZIMUTH FR~M ROTARY TABLE TO T~GET IS 63,92 SDI 3-41/X-39 ME~SUR~ DEPTH ft 0,00 453,00 ?88,00 1i73,00 i340,,~ ft ft 453,0 453,00 5.~_.,0 I85,0 117'2,98 t67,0 13.!.9,9¢ ~********.**** ANA. DRILL SUEYEY CA~CiJLATZONS ************AVERAGE .~GLE f£1~dO5*~*** TARGET STATION AZI~TH LATI lq]DP. SECTION !NC~, N/-S ft deg deg ft 0,00 0,00 C,'.t)O 0,~ 0,21 0,50 320,00 1,~ - 2. ~ O, 25 26C. ~0 3,05 -2,98 0.50 330.00 3.57 0.09 3.00 52..30 8.57 DP. PARTURE DISPLACEMENT at ft ft 0.00 0,00 -0.~ 1,98 -3.97 5,01 -5,~ 6,19 -4,09 9.50 AZIMUTH 340,00 30,".60 305,16 334.49 DLS dec/ lOOft 0,00 0,11 0,08 0,26 1,78 1704,00 2!69.00 ~ A 2569,00 2663.00 364,0 1703.44 465.~ 2167.81 277,0 ~'"' 3~ 12~.~ 2~<7,04 94,0 2660,70 18,31 2,75 68..~ 17.70 11,72 21,23 ~.51 0.23 42.58 3.~ .~.30 26,82 34,28 43.53 51.97 0,il 58,80 3,50 72.00 32,40 49,6I 59,25 55.85 0.12 67,15 4,30 ,~,~0 35,56 57,34 67,49 %,1~ 0,81 75,18 5,50 62,80 39,23 64,~) 75,49 I~,69 1,28 2757.00 2846,00 2937,00 3060,00 3152,~ 94,0 ~754,!7 89,0 2842,44 91,0 29~2,38 123,0 3053.29 ~.~ 3142,~ 65.07 6,60 ~.10 43,96 96.42 8,I0 58,60 49.77 Li0,22 9,40 ~,'c"O 56.81 i32,80 11,80 60.~0 68,08 t53,99 14,90 5~.50 78,76 73,20 85.39 59.01 1,21 62,?~ 96.77 59.05 1,70 94,91 110.62 59.(;9 1.45 114.53 133.24 59.27 1.'~ t32,89 154.48 59.~5 3.37 3276.00 3399,00 3477,00 3608,00 37~),00 124,0 3260,93 123,0 3374,65 78,0 3445.28 131,0 191.54 ~0.50 58,20 98.26 238,25 24.30 6C,ZO 122.26 ~1.22 25,90 58,00 139,26 :i31,29 29,10 ~f.20 172,11 377.49 31,80 56,30 198.01 165,16 192,15 59,25 4,53 205,42 239,05 57.2~; 3,15 233,81 272,14 59.22 2.37 284,.~ 332,59 5~t.84 2,52 o~.~.37 379,18 58,52 2,94 3886.(X) 1~,3 3794,45 4074,00 188,0 3939,62 4~6,00 i52,~ 4(M8,70 4415,00 .189,0 4177,12 4727.00 3!2,0 ~B1,38 36.80 ~,30 2~.17 410,57 483,93 59;.56 41.90 56,50 322,14 5~.85 603,09 704,69 46,~ ~.I0 380,~ 598,09 709,13 M1,78 47,80 5~,40 460,03 7!2.04 847,72 1067,68 46,.~0 5E,70 594,64 ~97,66 1076.75 57,71 ~":_-, ,50 57,13 56.48 2.69 2.71 3,10 0,92 0,36 50.36,00 5316,00 5566,00 5726,00 5882.00 309,0 4602.38 2~).0 250,0 4963,29 !56,0 5165,4I 1288,19 45,70 56,30 722,67 i488,62 4.6,80 56,10 8;.~,19 1572,65 49,20 56.00 938,'~ i793,20 49,70 ~..?0 !006,14 1911.23 49.50 57.90 1070,14 .~g 1._297'?,90 ~,22 0,70 1248.58 1502,16 56.22 0.40 1402,69 1~7,94 ~5,20 0.'76 1504,01 1809.52 56,22 0,53 1604.09 1928,29 56.29 0.50 6073,(X1 6198.00 4~,00 o~8,uO I?1,0 5292,% :~ ^ 5375.~~ 214~0 5516.46.' 286,0 5704,84 36~,0 5946.76 2055,44 49,10 59,~ 1145.26 2149,~ 48,60 58,40 1193,74 2309.52 48,80 6C,FO 1275.21 2524,03 '.46,80 58,~ !384,92 ~99,73 49,00 ~...50 1532,89 1727,89 2072,97 56.46 0.71 18C~,57 2167,01 SS,57 0,83 i9a7,t6 2327,58 56-78 0,81 2i.32,29 2542,57 ~/,00 0,71 ooo.~ ~ .... 57.07 0.12 7450,00 7.K-)9,00 7905,00 8095,00 8289,00 384,0 6197.87 18%0 6320,16 266,0 6490,43 i.u,O 6810,39 !94,0 6730.49 3088,57 49,40 57,40 1689,29 3231,68 49,80 5~,~0 1765,~ ~ '""' .e . o4.a4,.~ 50,..40 56,40 187A.40 ~80,77 51,10 5~,_'50 1957,83 3731. ~ S2.40 56.20 2042.25 % ~.1I,$5 ~110,54_ J~=', 11 0,11 2733.64 3254,46 57+14 0.39 2905.61 3458,82 ~,15 0,60 3028,41 3606,16 57.12 0,27 3155,23 3758,50 57,09 0,68 MEASURED I'{:RVAL V~TICAL DEC'TH 8497,00 20~,0 3658,(~ 1~1 ?034,00 376,0 71~49 9783,00 366,0 7662,7~ ************* ANADRiLL SURVEY CALCUL~'TI~$ ********.***'*AVERAGE Ai~£:I.i~ METHOD********* ?AR~ET STATION AZIMU.'H LATITUDE SECTION INCLN, N/-S · ft deq d~g ft 3896,68 52,70 65,40 2122,81 4022,75 ¢O.~,,.,v~a ~,~ 2!71,94 4313,96 51,40 66,50 227~,~ 4612.12 51,30 68.~0 2387,95 ¢~95,76 50,80 68,90 2491,34 ,:,- 41/.R-39 DEF'AR~RE DISPLACEMENT at AZ!~TH ft ft de,.] 32'.'~,38 3923.Z~ 3415..49 4047,75 _~,. 3687,84 4334,85 .~,.6,t4 ~29,53 4~1,34 4910,29 59,5! DLS de9/ l®ft 3,51 2,11 0,22 0,02 0,16 ?970,00 10158.00 1035!,00 1O545,00 187,0 w~o il !88,0 79c~,08 t'~.0 8031.84 189,0 8159,77 189,0 8289..~ ~{~{,03 49,90 7C,40 2541,41 5181,~ 49,20 70,00 2589,87 5324,94 47.90 7!.30 262~,16 5462.92 $5,90 71.50 2682.~ S598,37 46,00 75.50 2724,07 4366.33 5052,09 59.,~ 0,78 4500.94 5192,87 ~.08 0,4I 4~7,30 5335,21 63.~6 0,78 4769,04 5471.89 ,.40,64 0,56 4899,,~ 5606,02 60.93 0,90 10918,00 i~100,00 11288,00 11474,00 !16.~,00 !89,0 84~.81 182.0 8~3,62 188.0 8690,33 1~,~ 8826.47 189,0 8966,37 5730,44 44,70 76,~M 2759,44 $55,30 43,40 7¢,50 27~.91 5983,52 43,30 70,40 2839,09 6L09,35 42,~ 71.10 2880,88 ~3~,~5 41,90 71,60 ~B21,51 5029,40 57.36,67 .51.25 1,17 5150,58 5850,51 61.51 2,22 5272.19 59&~.02 61,70 0.06 5391,84 6113,21 61.88 0,46 5512,24 ,o~ ._ ~.59 ~?.08 0,41 11986,00 ~125,~ 1218,00 12312,~ !82,0 9102,89 141,0 92¢~.55 1~,0 9314.69 93,0 ~84,88 74.0 9455,,~ ~54.~9 40.'~ 72.30 ~"~," i 6445.83 40,80 72,60 2987,15 6535.60 40.'-R) 72.40 3013,73 6595,85 41,10 72~70 3031,51 5626,58 6357,26 62.26 0,57 5714.44 64~.09 62.40 0.29 5801.38 6537,48 62,55 0,38 5859,75 6597.48 52.65 0,54 59!8,86 .~57,96 62.75 1,36 12405,00 i2500,~ 12597,00 1~-~,. 93,0 9526,17 95,0 9598.19 97,0 9671.73 !01,0 9815,99 6716.40 41,00 7~,60 3%5,03 6777.i4 40,40 :~,?0 3080.80 6838,94 41,00 76,60 ~95,83 39~,63 42.~ 76,~0 3110.39 6968,21 44.30 77,30 3125,94 5977,57 6717,57 62,.85 0,21 6037,47 6778.08 62.,97 ! ,09 6098.~ .A837,66 ,~.09 0,78 6160,48 6901.16 o'3 .z"l 1,58 6228,11 6968,56 63.35 1.81 12887 12976,00 ?4.0 9;~.-2,23 89,0 9943,04 70.33,02 46,10 ~.)0 3140,26 7095.94 47.70 78,?0 3153,33 6293.25 7033.23 63,48 ,~.~:.~ ~0¥6,04 &3.62 1,97 1.98 PAC. I~ **~***** SCHLL~B~ **~,,, ***~,~ ***************************************************** C[~'ANY SAPC WELL ~M£ SDI 3-41/K-~? LOCAI'ION I ~NDICO?? SOl LCCATION 2 5 .,kXIS DA~: 02-D~-e.8 ~,GNFI'IC DECLINATION 31, I0 ************* ANAORILL ************** 9]E¥£¥ ANALYSIS ************AV~lGE ANC;[E ME?dOD********* SDI 3-41/E.-39 MD ft TVO t~ C~ -- f t deq. 0,0 0,04 0.00 453.0 453,00 0.50 9.o..8.0 987..o8 -0,25 1!73,0 1172,98 0,25 t340,0 1~:~..,90 2,50 O~[NC C~ I RAT£ A~ CH(; Cb~AZM CHG l%$:N RATE ,teg deg/100ft deg d,?g deg/100ft 0.0} 0,00 0.00 C.O0 0,00 0.50 0,1I .-40,00 -40,00 -8.83 ).25 -0.~ -60,.~ -I~.00 -11,21 0,50 4,85 70,00 -30,00 37.84 3,CQ 1,50 82,00 52,00 49,10 CLOSURE TOOL FACE DLS DLSRT ft deg deg/lOOft d~lOOft**2 0,0) 0.00 0.:~0 ¢.00 1,97 0.00 O.tl 0,02 4.49 150,09 0.38 O,O1 5,43 98,91 0,26 0.10 0,00 0.00 i,F8 0,91 bO4,0 2169,0 2446,0 2569.0 2663,0 t703.44 -0.25 2167.61 0,50 2444,33 0.25 2~7,04 2660.70 1,20 2.~ -0.07 1~.00 68,00 4,40 3,25 0.11 0.00 ~.00 0,00 3.50 0,09.' 4.00 72.00 1.44 4,30 0,01 -8,80 6~.~-0 -7,15 5,50 1,28 -0.40 62.80 -0,43 10,75 115,19 0,23 0,43 9.02 0,00 0.11 0,03 7.29 45.05 0,12 0o01 6.75 41.2~ 0.8i 0,56 9.50 91.55 1,28 0,50 2757,0 2846,0 2937,0 3060,0 3152.0 2?J~,17 1,10 2842.44 1.50 2t~2,38 1.30 ~0~-~, 2.40 3142,~0 3.10 6.60 1,17 -2.70 .%.I0 -2,87 8.10 1.49 -1,50 58.40 -1,69 9.40 1.43 1,60 ..~',20 1.76 ti,80 0,01 -0,i0 60,!0 -0,C..4 14,90 3.37 -0.60 59.50 -0,65 7,31 15,74 i,~I 0.07 8,21 7.93 1,70 0.55 9.30 11,.5t2 1.45 0,27 10.79 0.00 1,95 0.41 6.~ 1,71 3.37 1.55 32,';'6,0 3399,0 3477,0 ..--..08,0 3700,0 3260,~3 5,60 337n,65 3.80 M~.~8 1,60 3640.79 2,70 20.D 4,52 -1.~ 58,20 -1.05 24,30 3,09 2,00 25,% 2,05 -2.20 58.00 -2,82 29.10 0,00 -1.80 5620 -1.37 31,~ 2,93 0,I0 56,30 0,11 15,65 4,64 4,53 0,93 19.51 12,25 3,15 1,12 22.29 31,24 2,37 1.00 2~.47 15,35 2.52 0,11 12,32 2.79 2,?4 0.45 .3886,0 4074,0 4226,0 4415,0 4727.0 37~.45 5.00 393%82 5,10 +M&,70 4,70 4177,12 1.20 45~8,70 -1.00 36.80 2,69 0.00 56,30 C,00 41,90 2,71 0,20 56,50 0.11 46..~3 3,09 -0,40 5~,10 -0.26 47,&0 0.01 -1,70 54.40 -0,?0 ~c.,'O -0.22 46,80 -0,32 -0,70 =" ~ 49.59 0,~ 2.59 0.13 65,19 1.49 2,71 0.01 79,26 3.53 3.10 0,25 100.i6 46,~ 0,'92 1,15 35,69 0.87 0,34 0.18 50~,0 5316,0 5566,0 57?6.0 5882,0 46u~.~8 -1,I0 4~,o.® 1,10 4963,29 2.40 :~.~; 0,50 5168,41 -0,20 45,70 -0.34 2,60 =a ~ ;.,=u 0,84 46.80 0.39 -0.20 ~.!0 -¢.07 49,20 0,76 -0.10 56.00 -0,04 49,70 0.02 0.90 ~,?0 0,56 49.50 -0,13 1,(g) 57.90 0,64 174.08 121,25 0,70 0,11 201,25 7.45 0,40 0,11 226.68 1,70 0,96 0,23 242,49 54,10 0.53 0,27 I~.47 I53.04 0,50 0.02 6073,0 6198.0 6412.0 6698.0 7066.0 ~2So.% -0,40 5375,22 -0.50 55!.6,46. 0.20 5704.84 0.00 5946.76 0,20 49,10 -0,21 1,70 =~'' ;r,~ 0,89 · IO,~ -0.40 -I,D 58.40 -0,96 4~,80 0.09 2.30 ,~).70 1.07 ,18.~ 0.0I -2.D 58.00 -0.94 49.00 0,05 -0,50 b-Z~50 -0.14 269,03 107.60 0.71 0,I1 277,10 119,36 9,83 0,10 289,35 84.16 0,~i 0.01 306.50 90,89 0.71 0.04 255.98 105,04 0,12 0,16 7450,0 7639,0 7905,0 8095.0 8289.0 6197.67 0,40 6~D,16 0,40 t ~,~ o4~v,43 0.80 66[0.~¢ 0.50 6730,49 1,30 49,40 0.10 -0.10 57.40 -0,03 49.60 0.21 0.80 58,20 0.42 50,60 0.30 -1,80 56.40 -0.,~ 51,10 0.01 0,10 5~.50 0,05 52.40 0.67 -0.L'Q 56.20 -0.15 369,06 9,41 0,11 0,00 .384.40 56,94 0.39 0.15 407,96 60,53 0,60 0,08 427,12 7,57 0,27 0,18 ~6.30 62.14 0,68 0.21 SDI 3-41;'I(-39 MD '(':~0 DC_C',~ CI.~[,',~_C~ I_RATE AZM__r':I~ CdMAZPI_CHG TL,~N_RAT~ ft ft d~g deg deg/lOOft deg deg deg/lOOft CLOSURE TOOL FACE DLS DLSRT ft deg deg/1OOft deg/lOOft**2 0477.0 6856.97 0.30 52.70 0,14 9,20 65,40 4.42 456.18 ?0,45 3.5i 86~B,0 6956.87 -2.10 50.60 -1.30 3.40 ~8.80 2,11 449,17 129,27 2.11 0,87 9034.0 71~3.4, 0,60 51.40 0,21 -0.30 68,50 -0.08 425,0B 15,16 O.Z2 0,50 9417.0 7432.70 -0.I0 51..30 0.01 0,00 _8.~0 0.00 401.I9 0,00 0,02 0.05 9783.0 7,~2,78 -0,50 50,80 -0.14 0,40 ~.?0 0.11 447,!9 10,29 0.16 0,04 9970.0 7782.I1 -0.% 49.90 -0,48 1.50 70,40 0,80 363.10 128,41 0,78 0.33 10158.0 77(N.08 -0.70' 0.20 -0.37 -0.40 70,~ -0,21 347.45 156,71 0,41 0,20 10351,0 8031,84 -1,30 47.90 -0.67 I.~ 71.00 0,52 .330,87 150,39 0,78 0.19 10540.0 8157,77 -!.00 46.~0 0,03 0.50 71.50 0,26 313,12 lbO.Ob 0.56 0.!1 10725',0 8289,99 -0,?0 ~$.00 -0.48 2.00 73.50 1,06 377,47 148,29 0,'?0 0.18 10918,0 8422.81 -I.30 44.70 -0.69 2,50 76.00 1,32 267,42 127.04 1.17 0.14 I1100,0 8553.62 -1.30 43.40 -0.71 -5.50 70,50 -3,02 246,91 110,74 2,22 0,58 11288,0 86~0.LL3 -0.I0 43.30 -0,05 -0,!0 70,40 -0.05 232.~ 148,73 0,06 1,15 11474.0 882~,47 -0,70 42..~ 0,0I 0.70 71.10 0,~ 217,16 146.01 0,46 0.21 11.~3~0 8%6,37 -0,70 41.70 -0.37 0.50 71,~ 0.26 2'?2,6~ 122,53 0,41 0,02 11845.0 7102,89 -1,00 40,90 -0.55 0.40 72,~ 0.22 184.22 i65,40 0.57 0,09 11986,0 92(;9,55 -0,t0 40,~ -0,07 0.60 72,60 0.43 i70,78 104,~ 0,29 0,20 12125,0 9314,69 0.10 40.?0 0,07 0.80 73,40 0,58 156.44 79,46 0,38 0,07 12218.0 9~x.~ 0,20 41,10 0.03 -0,70 72,70 -0,75 146,75 .%.67 0,54 0.17 !~12,0 9455.88 -0.30 40.b3 -0,32 t,90 74,60 2,02 200,73 154.60 1,36 0,88 12405,0 9526.17 0,20 41.00 0.22 O,~X} 74,60 0.~ !25,06 0.00 0.~! 1.24 12500,0 7590,19 -O,,.q) 40,40 -0,63 !.30 75,?0 1,37 112,89 125,80 1,09 0,93 12597,0 %7[.73 0..50 41,00 0,62 0,70 7~,60 0,72 99,38 37.44 0.78 0,33 126¢2.0 9742,61 1,50 42,~ 0,01 O.D 76.80 0,21 85.39 5.06 1,58 0,85 12793,0 9815,?~ 1,80 44,30 1,78 0,50 77.30 0.50 1'._-16,34 104.28 t.~l 0,23 12887.0 ?852,23 1,80 ¢%10 !.91 O.bO 77,90 0.64 53.85 13.50 1,97 0.16 12976.0 '~74:3,04 1,60 47,70 1,80 1,00 7~,90 1,12 37.60 24,85 1,78 0,01 PAGE NO, ********* ANADRI[L ********** ********* SCHLUM~E~]~ ********** ***.****** ********** *************************************************** ~********** SURJEY F~O]RAM *********** COMPANY SAPC W~LL NAME SQl 3-41/K-~? LC~ATION 1 ~DI~TT SOl ~CATION 2 6 AXIS MAP~P.T!C D~L!NATt~ 31,10 02-DEC-88 ~L ~$]MB~: 41 WB~L H~AD LOCATION: LAT(N/-S) 0,00 QEP(E/-W) 0,00 TiE IN POiNT(TIP) ~SUR~D D~PTH 0,00 TRUE V~RT D~F'TH I.NCLINAT~ON 0,00 AZIMUTH 0,00 LATITU])E(N/-S) 0,00 DEP~TIJRE(E/-~) O~,,X) AZIMUTH PROM ROTARY TABLE .TO T~:G~ IS 63,~ SDI 3-41/~-39 NEASUR~ iNT~%'AL VER?ICAL DEF~rH · ft ft ft 0,00 0.0 453,00 453,0 453,00 988,00 535,0 1i73.00 !85,0 117~,98 1340.,~ 167.0 1~9,?¢ 4.***~****** ANAl)RILL SUR¥~Y CALOJLA?!ONS ***********~AVERAg£ ANG%6 TARGET STATION AZI~]TH LATIIq_~£ SECTION INCLN, N/-S ft deg deg ft 0,00 0.~ C,~O 0.00 0.21 0,50 320,00 1.86 -2,22 0,25 266,.30 3,05 -~.78 0,50 330,00 3,57 0.09 3,00 52.~) 8,57 D~PAR~.$~£ DISPLACEM~T at AZ!MU'~ ft ft deg_ 0,00 0.00 ).00 -0,.~ 1.98 340,00 -3.97 5.01 307..~0 -5,06 6,19 305,16 -4,09 9,50 334.49 DLS de~ tOOft 0 0,11 0.08 0,26 1 1704,00 2169.00 2446.00 2663.00 3~4,0 1703,44 465.g 2167,81 277,0 2444.33 123,0 2567,04 94,0 26_~,70 18.31 2.75 68.00 17.70 11.72 ~1,~ 73,51 0,23 42.58 3.~ .~8.00 26.82 34.28 43.53 51.?7 0.11 58,80 3,50 72.00 32,40 47,61 59,25 56.85 0,12 67,!5 4,30 .g~,~O ~¢5.58 57,34 67.49 58,18 0,81 75.18 5,50 62,80 39,23 64,50 75.49 58.69 1,28 2757.00 2846.00 2'}~7.00 3060~00 3152.O0 94,0 275.4,17 89.0 2842,44 9!.0 2'~2.~ 123.0 3053.29 92.0 o.N2,8C 85,07 6,60 59,.:/0 43,98 96,42 8.10 58,30 49.83 110,21 9,40 !32.78 II.80 59,80 68,30 i53,96 14,90 ~7.=0 79,08 73,19 85,39 5?.00 1,21 82.96 96,77 59,01 1,70 94.84 110.62 5?,¢2 1.45 114,40 I~,24 59.16 1.95 132.71 154,48 5~.21 3,37 o~1...,00 3477,00 3608,¢0 37~.00 124,0 02~,93 1~,0 3374.65 78,0 3445,28 131.0 3~1,48 92,0 3640.79 191,49 20.50 57.80 98.78 238.17 24.30 59.50 t~.13 ~. 1,11 -25,90 57.40 140,42 331.10 29,10 55,70 173,76 377,24 3!.80 55,60 200,07 184.85 192,18 59,07 4.53 204,90 239,05 59.00 3,14 2~ ~3,11 ~2,14 58.94 2.37 283.58 ~o~.Jo=° =8.~0 2,51 b-~_~.O~ 379,16 ~.15 2.94 3886,00 4074.00 4~6.00 4415,00 4727,O0 l&5.O 3794.45 188,0 39~.82 152.0 ~.",48,70 /,% 18:,0 4177.12 4388.:0 480,95 :36.~ 55_.,.50 259.29 598.91 41,90 55,70 326,54 703,84 46,60 55..,30 3&5.62 &40,62 47,80 53,.~ 467,25 10./,6,02 46,.~ 5~,10 604,12 408,56 483.89 57.60 2.69 506,98 603,04 57.21 2,71 594,39 709.06 56.96 3.10 707,21 847.63 %.55 0,92 891,t8 1076.64 55.87 0.34 5036,00 53t6,00 55.%.00 5726.00 5882.00 309.0 4602.38 28O,0 4796.~ 250,0 49_/,3.29 !60,0 5~7.30 156,0 51&~,41 1286,09 45,70 55,50 734.37 1486,18 46,80 ~.50 848,93 1.5.59,89 49,20 55,20 954,56 1790,26 49,70 ~.50 10~,81 7-' !908,22 49.50 5. ,:0 1087,34 1072,44 1~r.?,78 ~,60 0,66 I239,13 1502.04 55,58 0,39 1391,97 1647,.53 55,56 0.96 1492,58 1809.40 55.58 0.69 I592.32 1928,16 55,67 0.60 6073,00 6178,00 64!2.00 6698,00 7066.00 191.0 =~'"= "' i25.0 5375.22 286,0 5704,84 3,~.0 5?46.76 au,~.3l 49,10 58.80 1163.54 2145.94 48,60 57,50 1213,21 ~06,06 48,~ 59.~ !296.73 2520.27 48.80 57,00 1409,33 27'~.48 49.00 5~.70 !560.97 ..~.85 0.48 I715,46 2072,,~ == 1795,41 2166.~ 55,95 O.&~ 1932,78 2327,48 56.14 0.85 2116,16 2542.51 ~$,34 0.76 ~o o.J~ 2819.81 56.39 0.08 7450,00 7..~39,00 7905.00 8095,00 8289. O0 384,0 6197.67 !89,0 6320,16 266.0 64%,43 190.0 ~t0,3~ 194,0 67~0.49 ~083,83 47,40 56,60 1720,78 3226.68 49,80 57'.20 1799,38 3429,31 50.60 55,70 1912,~ 3575,16 51.10 55.S0 1995,Z5 3725.~ 52.40 55.50 2081,21 2591.16 3110,49 %.4I 0,11 2711,73 3254.42 56,43 0,32 2882.05 3458.78 7>5.43 0,53 3003,84 3606,12 56.4l 0,27 3129,62 ~'~ '~ SDI ' -' :3 4!/K-39 MEASUR£D Y. iTERVAL D~'TH DB'TH ft ft ft 8497,00 208,0 ~4,58,00 161,0 6956,87 9034.00 376.0 7193.49 9417.00 383.0 7432.70 9753.00 366.0 7862. SURVEY CAI. CULATIONS TAF~ET STATION AZIMg'Td LATITUDE SECTION !~LN, N/-S ft deg d~q ft 7q570.64 52,70 6~,30 2164,02 4016,82 50,60 67.70 2215.38 4:308,43 51,40 67.50 2326,73 4606.97 51..30 67.,;0 2441.44 4870.'~ ~).80 68.~ 2549,45 DEPARTURE DISPLACEM£NT at AZImuTH E/-W ft ft deg 3272.48 3?23,28 %5.52 0087,83 4047,88 55.82 3657.9? 4335.27 ==.z.. =' ~ 3~4.23 4630.2I !!8.18 4197.58 4911.15 58.73 DL$ deg/ 10Oft 3.36 2,11 0.22 0,03 0.19 9970,00 10158,00 I0~1,00 I0540,00 10729,C$ i57,0 188.0 7904~08 193.0 m)21.84 189,0 815?.77 189.0 8289,99 5034.49 47.?0 69,20 2601.98 5176,96 49.20 ,59,10 2652,90 5320,92 47,'~) 7C,30 2703.44 5459.18 46.90 70,60 2750.34 55?4.98 46.~ 72,30 27'~,92 43Jl.64 5053.06 59.0I 4465.~ 5!73.95 59.29 4600.88 5336.35 59.56 4731.85 5473,10 59,82 4861,72 5607,34 60.12 0.69 0.37 0.76 0.58 0,81 10918,00 1!100,~ 11288.00 11474,00 !16JJ.O0 189.0 8422.81 182.0 8553.62 188.0 8690.33 l&5.0 $S26.47 189,0 89~.37 5727.~ 44.70 75,60 2831,09 5352,51 43,40 69,40 2869,15 5980.98 43.30 69,40 2914.55 6107.05 42.60 7C,10 29~.42 6Z'~,28 41.?0 7!,00 3~300,73 47'~0,94 5737,79 ~0.44 1.42 5111.62 ~61,80 60,69 2.47 52"32.42 5?89.40 60.88 0.05 ~o,1.32 6114.64 S~.¢6 0.46 5471.15 6240,02 61.26 0,49 I18q5,00 Ii984,00 12125,~ 12218,00 i2312.C~ t.52,0 91C2.89 141,0 92~,55 I~¢,0 9314.69 93,0 ?384,88 94.0 9455.,~ 6352,72 40.?0 71,00 3039.'F2 6444,24 40.80 71,00 ~.69.94 ~ ~ 7I 6034,3? 40.?0 ,80 3098.94 6594,85 41.10 71,50 31!8,15 6655,71 40,60 7~.~ 31~.31 5584,'~ 6355,67 61,44 0,55 5672,15 6449,64 ,6!.58 0,07 5~8,32 6539,24 61,71 0.38 5816,23 65~h35 61,80 0,30 5875,i0 6659,62 61,91 1,9I 12405,00 12597,00 12692.00 t27~,00 93.0 9526.17 t;5.0 9598.19 97.0 9671.73 95.0 9742.61 101,0 9815.99 6715d~ 41,00 73,80 3153.10 6776,56 40,40 ~,t0 3i69.71 &_~.56 41.00 75,60 3185,70 67C~},51 42,50 75,50 3201,44 6968.38 44.30 76.30 ~18,28 5~33.63 6719.37 62~01 0,35 5913.31 6779,88 62.13 1,09 6054.51 $84!~48 52,25 0.70 6115,70 6903,04 62,37 1,58 6I,~.10 6970,51 62.50 1,84 12976,00 ?4.0 ?882.23 89.0 'Yf43.04 7033,48 46,10 76,70 32~.85 7096.71 47.70 77,60 ~48.~0 62a7,96 7035.25 62-63 6311,34 7ff~8,15 62.77 1.94 2.01 PAG£ NO, *~******** SURVEY ~ALYSIS *********** C[~'At~' SAPC ~LL NAME SDI 3-41/E-~9 ~..~ I D~O!CO~T SOl LCCAT!ON 2 6 AXIS DATE: C,2-DEC-~ MAGNETIC DECLINATION 31,10 WELL NUMB~ 41 ' ?A6E'NO, 2 SDI 3-'~1/K-39 ************* ANADRILL ************** SL~911Y ANAL'rSlS ************AVE(AGE ANG~ METHOD********* ~D ft '!'VO i""~ CHG ft deg ~J~I-'.'IC C~ I RATE AZM ~ CJMAZM CHG TURN deg deg./100f~ de9 deg de.q/100f~ CLL-U4JRE TOOL F~E %S DLSRT ft deg. d. eg/IOOft dt~.~'lOOft**2 0.0 0.0) 0,00 453,0 453.00 0,50 ?88,0 ?~?.98 -0,25 1173,0 **~ z~/~,98 0.25 1340,0 I~?~?0 2.50 O,CO 0,00 0,00 0.00 0.50 O.ll -40,00 -40,00 0,25 -0.05 %0,00 -'I00.00 -11,21 0,54. 4,85 70,00 -30,00 ._v~",84 3.u0 i ,50 82,00 52,~ 49,10 0,~ 0,00 O.fX) 0.00 1.97 0,00 0,11 0,02 4.49 150.09 0,08 0,01 5,43 98,91 0,26 0,10 0,00 0.00 t.f8 O.?l 1704,0 2169,0 2446,0 256~,0 26&3.0 ~/u~,44 -0,~ 2167,01 0,50 2444,33 0,25 2~+7.04 0,~0 2660,70 1,20 2.75 -0,07 16,00 68.C0 4,40 3.25 O.lt 0,00 ..~o.00 0.00 3.50 0.09 4.00 72,00 1,44 4.~3 0.01 -8,80 .~'.20 -7.15 5.50 1,28 -0,40 62.80 -0.43 10,75 115,19 0,23 0,43 9.02 0,00 O.ll 0.03 7,29 45.05 0,12 0,01 6,75 41,24 9.50 9!.55 1,28 0.50 2757.0 2846,0 2?37.0 3060,0 3i52.0 ~,.;-.~, 1,i0 3053.29 2,40 ol.'~z,~ 3,10 6.60 1,17 -2.90 59.90 8,10 1,69 -1.60 58.30 -1.80 9.40 1,43 1,60 59,90 1,76 11.80 0.01 -0.I0 59.80 -0.08 i4,90 3.37 -0,$0 5'}~D 7,32 16.88 1.2! 0.07 8,28 8,43 1,70 0,55 9.44 11,32 1.45 0,27 11,05 0,00 1,75 0,41 6+88 1.7! :3.37 1,55 3276,0 3260,93 5,.M · ~99,0 ~7~,65 3.80 3477,0 ~ ~ ~ 3608,0 :~ft,48 3,20 20,50 4.52 -t,40 0/.80 '1.13 24,30 3,09 1,80 5%60 1,46 25,'?0 2,05 -2.20 57,40 -2,82 29,10 0,00 -!.70 55,70 31.~0 2,93 -0.10 55,60 -0,11 16,25 5,00 4,53 0,93 20,51 11.06 3,14 1.I3 23,64 31,24 2.37 0,98 31,40 14,53 2,5! 0.11 12,69 2.79 2,74 0,46 3886,0 4074,0 4226.0 4415,0 4727.0 37~n,45 3939,82 5.i0 4016,70 4,70 4177,I2 1,20 4388,70 -1.00 o..80 2.69 0,00 _..60 0.!30 41,M'o 2,71 0.I0 55.70 0.05 46,60 3,~¢ -0,40 55,30 -0.26 47.~ 0o0I -1,70 53,60 -0,?0 46,80 -0,~ -0,50 5~,i0 -0,16 53.~? 0.00 2.59 0.13 70.42 0,71 2,71 0.01 85.~5 3,53 3,10 0.?_5 108,76 46,68 0,92 1,I5 38,10 0,87 0.34 0,18 5036,0 5olo.0 5566.0 ~/~6,0 4o0~,o8 -I,I0 4?;6,00 1,10 4963.29 2,40 5O67,3O O.50 o!o~,4I -0.20 45.70 -0.36 2.40 55,50 0,78 46.80 0,~ 0.00 55.50 0,~ 49.20 0,96 -0,30 55.20 -0,12 49,70 0.02 i.~ .v 0.8! 49,50 -0.13 1,20 57,70 0,77 188,13 123,22 0,,.% 0.10 217.74 0,00 0.39 0.10 245,43 5,36 0,96 0,23 262,49 63,56 0.69 0.17 I50,82 160,00 0.60 0,06 8073.0 6198.0 6412.0 6698,0 7066.0 52;2.'76 -0.40 o/~,22 -0,50 5516,46. 0,20 5704~84 5?46.76 0,20 4%10 -0.21 I.I0 58,80 0.58 48,~ -0.40 -1,30 57.50 -I,04 48,80 0,09 2,40 59,90 1,12 48.80 0.01 -2.90 57.00 -1,01 49.00 O,(Y5 -0,30 5~.70 -C.08 290.91 115.'?? 0.48 0,06 300,37 I17,49 0,88 0,32 315.00 84.46 0,35 0,01 o~ 9 " ~5,51 .0,~5 0,76 0,03 276.60 102,74 0,38 0,19 7450,0 7639.0 7?05.0 8095,0 8289.0 6!97.67 0,40 6320,16 0.40 6490,43 0.80 6610,~ 0,50 6,°0.49 1.30 49.40 O,lO -0,I0 56,60 -0,03 49,80 0.21 0,60 ~.20 0,32 50.~ 0,30 -1,50 55.70 -0.56 51,10 0,01 0,10 ~',80 0,05 52,40 0,67 -0.~ 55.50 -0.15 406,43 9.82 0,I1 0,01 424,02 48,96 0,32 0.!1 450.59 55,71 0.53 0.08 471,53 7.57 0.~* 0.14 369,64 48,51 0,68 0,21 ************* ANADRILL ~************* SL~V£Y ANALYSIS ************AVE~.'AG£ ANGLE M~ll40t)********* ~DI 3-41/E-i~ MD TVQ [NC C~ CL~[NC CHG I RATE AZM CHG C'JMAZM CHG ~_~N RATE ft ft deg deg deg/100ft deg deg deoy'100ft CLCk~JR£ TOOL FAC£ N.S DLSRT ft de9 deq/100ft deQ/'lOOft**2 6497.0 6656,77 0.30 52,70 0,14 6.80 84,30 4.23 505.02 90,22 3.36 1.29 6658.0 6956.87 -2.10 ~.60 -1.30 3,~ 67.70 2.1! 500.43 129,27 2.11 0,78 ?034,0 71~3,49 0.60 51.40 0.21 -0.20 ~7.50 -0,05 48!,6~ 10.6~ 0.~2 0.50 74!7.0 7432~70 -0.!0 51,30 0.01 -0.!0 .$7.40 -0,03 463.26 144.07 3.03 0.05 ?783.0 7'.~.~,78 -0,50 50.~3 -0.14 0.60 68.~0 0,I6 493.44 10,29 0,19 0.04 ??70.0 7752.il -0.90 47.90 -0,48 1,~ 69.20 0.64 432.75 134,63 0,69 0,27 10158.0 7?Ca,~ -0,70 49,20 -0.37 -0.I0 69.10 -¢.05 417.71 174,~. 0,37 0.17 10351.0 8031.84 -1,~ 47.'~ -0.67 0,90 70,00 0.47 405.52 152.91 0,76 0.20 10540.0 8159.77 -I.~ 46,q0 0.03 0.60 70,60 0,32 390,~ 156.48 0,5~ 0.i0 I0727.0 8289,99 -0.% ~5.00 -0.48 1.70 72,30 0,?0 444,50 137,19 3,81 0,12 10918.0 842~.81 -1,30 44.70 -0,69 3,.30 75.~ 1.75 348,69 120.13 1.42 0.32 11100.0 ~.5~,62 -1.~ 43,40 -0,71 -.5,20 69,40 -o,4! 329,81 I09,00 2..47 0,58 11268,0 ~6~0.33 -C,lO 43,30 -0,05 0,00 67.40 0,00 317.47 0.~ ' 0,35 1,29 11474,0 8825,47 -0,70 42,60 0.02 0,70 70,10 0,38 304.61 146.01 3,46 0.22 11~3,0 8966,37 -0,70 41.?0 -0.37 0.?0 71.00 0.48 372.11 126,74 0,49 0,02 11845,0 9102,89 -I,~ 40,90 -0.55 0.00 71,00 0,00 275,11 0,00 0.55 0.03 11986,0 72C9.55 -0.10 40,80 -0.07 0.00 71,00 0,~ 263,74 0.00 0,37 0.34 121~.0 73!.4,69 0.10 ,~.~0 0,07 0,80 71.80 0,58 251,90 79.46 0.38 0,~ 12218,0 ?~a.68 0.20 41.10 0,05 -0,30 71,50 -0.32 243,70 44,16 0,30 0.09 12312,0 9455.88 -0,30 40.50 -0.32 2,70 74.20 2.87 287,74 137,50 1,?1 1,71 12405,0 7526.17 0,20 41.® 0,~ -0,40 7S.60 -0,43 220,48 52.56 0.35 1.67 12500,0 759~,19 -O,.W ~,40 -0.63 1.30 75,10 1,37 212.16 125.80 1.0~ 0,78 ~J~.v~'~"'*' ^ 9671,73 0.60 41,~) 0,62 0.50 ~,60 0,52 ~..2 28.60 0.70 0,40 12672,Q 7742,61 1,50 42,~3 0,01 0,00 75,60 0,00 186.82 0,00 1,58 0,72 12793,0 96J. 5,'~ 1,80 44,30 1,76 0,70 7~,30 C,69 234,13 100,64 1,~4 0.26 12887,0 ?882,23 1,80 46,10 1,91 0,40 76,70 0,43 157,62 9,08 1,94 0.10 12776.0 9943,04 1,60 47,70 i,80 1,!0 ,--U'.30 1,24 142.64 '27.02 2.3! 0,08 STANDARD ALASKA PRODUCTION CO. SDI $-41 ( 14-3-II-17 ) K 39 Controlled Drilling Consultants, LES HENDERSON~'' 333-1552 Inc. CONTROLLED DRILLING CONSULTANTS, INC. P.O. Box 190560 Anchorage, Alaska 99519-0560 (907) 333-1552 December 1,1988 Mr. Brian Rose Standard Alaska Production Company Pouch 196612 Anchorage, AK. 99519-6612 RE: Magnetic Single Shot Survey Job No. A-1188-008 Well: K-39 SDI 3-41(14-3-11-17) Endicott Field North Slope, Alaska Date of Survey 11-8-88 to 12-1-88 Dear Mr. Rose- Please find enclosed the "Original" and six (6) Copies of our Magnetic Single Shot Survey on the above well. The method of Calculating this survey was Radius of Curvature. The depth of the survey was O' to 12,976'. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants, Inc. Cecil Harrington · ,.',. Directional Supervisor , ' ,:~, 0il.& {las Cons. Commissb, .... -- -- -- HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. WELL 3-4t/K-;59 (t4-3-1t-17) ' RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE: I"= I000' - ' DECEMBER 5, '1988 .. ?- '~- ..... "- · ....... . ...... ;- ................. 5 ...... *' ......'-'-'. .... I . .;_ ....... : ........................... . .,.. . ._'! ........... ! ................ ; ...... -.'._.:,_ . ; ........ ,_ _ _ -: ___' .............. ! ~ ~- ................................. . · . . ; . , ....... ~ .............. ---7 ........... -'-~--~ .... ; ........... --' ............ ...... . .............................. · ..... - ........ ..... ' ............................ ~ ........................... ~ .... 7-, ........ ; . ! ................................. , , ......... . ........................ ................... '" .............................. -- ;--TVD = . . ) - ;- ............ ; · .: .-- , ,. , '_., . . ~, !--; ....... -~-:. · , : : . , ;. · { . '. ....... ~ i ~ ? : .--T---' :-'T- , , i : * " ~ : ..................... ' ...... ; ---' ............. 7' , ..... -~-~--"-' ;' - ....... ............. - ,. _' .... ~,' ................... - .............. : . . _ . . _ . ........ - ...... -,, . ._ . _ _ __ _ TRUE .... HEAs,---DR~F~T VEP, TICAL SUB DRIFT r"EPTH ¢INuLr.. DEPTH ............ SEA .......... D IREC ............ 0 .... 0 0 , O0 .......... ~5.30 N . OOE ...... 453 ....0-30 452-~-99 397,69 N40, OOtd .............. 932 ~. 68 t173 .....0-30 -t1'72~9B 't117,68 N30,O01~ ........ t340 ~ ~330r09 -}2~4~59 - blS~.OOE t704 .......... 2'--45 ...... i 703"~-43 1648,13 N68, OOE 2t69 ........ 3 ..... 15 ..... ~ J'6?",-'79 2112.49 N68. OOE 2446 3 30 2444.3I 23~9,0J NF2,00E ..... 2569-~4-4-'~567T0~ ....... 251 i-', 72 N63.20E ......... 2663 ........ 5--S O- 266 0'~' 60 2605.S8 2846 ...... 8- 6 2842-;-42 ..... 2787',12 N58.60E 3060 .... i-t---~e 3053T~5 .... 2997'~95 N60,IOE "-~276-'---20-30~32~0.e4 ..... 3205,54 ' N58,20E ...... 3399-'24 t--eq.374-r53 ........ 3319,23 -.- t-I6 O, 2 gE 3477 25-'54 -'3445~'t7 3389,8Z 1158,00E ...... 3608 -29~6~56t-T~5 ....... 3506'; 05 ...... N56.20E 3700--'3t .... 48~64'0-','6~ ....... 35~5,35 NS¢,30E ....... .......... RECORD OF SURVEY JOB NO A-1188-008 YELL. 3-41/K-39 KB ELEV 55.30 FT. SURVEY DRTE 11/08/88 PROPOSED DIR N6~.92E ............................. I'O'I'AL uOOR[ iNATES ,00 S t,51 t,I 2,66 N 3.14 N 7,73 N i6,83 N 25.94 31 ,52 11 34,70 t.I 38.35 N 43, 08 N 48.89 N 55,93 bi 67.20 N 77,88 N 97.37 N i2i.37 N 138,36 t.! i97,1t H 255.25 N t t 1 2 2 2 ............ DOG LEG .......... C L 0 S U R E S 8EVERti"¥' :---3ECTtOh D ISTAt. lCE .......ANGLE .......... DE~.i/-t OOF.T .......DISTANCE P i~ 8 .............. i,27 iJ I ,98 H .40 6. 0 bi ....... , 4.41 bi - -5,t5-.N--.-58--.-56 ..... 19 ~} ............. , 5.44 t,~ 6.28 N 60 .2 I I~ 4,55 ~ ....... 8-.-97-- N--.3.0-.-..29--. 38--td ......... i-., 33,77 E 42,59 N-.-5~ 2~--1 i .... E ................ . 49, 09 E 5~,34 N 57 17 54 E 56,82 E 66,58 H-.-58 35 5 E ............. , 63,97 E 74,59 N 59 3 S4 E .. i. 72,68 E ...... 84.,-49--.N-.S9.20-..2~---E .............. 1, 82,47 E 95.82 H 59 'JO 27 E ........... 1, 94,39 E ....... 109-,71 .... N--~9--20 54--E ........ i, E $32,34 t4-59 29 ~ E ................ i, E 153-,58--N---5~-3-i 44-E ........ ~ E 191,26 N 59 2S 42 E ......... 4, E 238,t2 N 59 2t 24.--E ................ E 271,20 N 59 ~9 Sl E 2, E 331,64-N-5~ 55-1t E ............ 2, E 378.22 N 58 35 26 E ....... 2. E 482.94 t4,01 32.37 64.62 04,87 33.26 84,04 22,80 09.97 OOO ............... 04? ..................... 2-:-.7'~ , i35 503 ........................ 069 17,4~ i 08 41 ,..7~ 45-2 ...... :i-;z I ..................... 84-~.-2~ 429 5i~ 935 ~-R~ ........................ .................. .SOHIO YELL 3-41/K-29 DINGLE SHOT SIRVEY JOB i'.tO R-118~-008 COf. iPUfER- 05 DEC 8~ KB ELEg. ..o,?;= 31) ,'--I .... , · ? ........... TRUE ~ ~' ' H E A S-;--DRIF-T--VE R-T-'t. e A L: ..... SUB DRIFT i DEPTH ANGLE ...... DEPTH SEA DiREC. · i ............. D--M ...... DEG ;/ -4'074--41--54----~939;59 -388,i-, 29 H56,50E 4~26--'46-36---4048';'44 ~g~3, ~4 N56, t OE ....... 4'4'15--47--4~ir-?6T85 ..... 412 ~-; 55 N54.40E 47'27' 4~--'48 .....4~88 ~ 43 4~33, 13 NS~, 70E ...... 50~'--45-~2--~602'; t 53~6 46"48 ..... 4~95,7~ 4740,43 N56,10E ,, 5566--'49~'~'4963'; O0 ' '4907,70 N56, OOE j ~,8~ NS?. 90E ~--- 6 t98-48-~8--53~47'93 ...... 5219 ,' 6~ N58,40E ,:/_ "64i2"'48-'486698_..48_4~704~.5555t6~"t7__'~460,87649,25 ' N60,70EN58,00E ~,.~ "?066--4~ .... O ....... 5946'v4~ ·5891, t6 N5F,50E 'z.?~TgOS'-"iO--36---d490~-'14 ~434,84 · N56,40E ,,{ 8095-5't ....... 6 .... 66-t-'0"~-t 0 .... 6554,80 N56,50E ~,~ ~49 r'-"5~--"4'~---~85~--~ ~8 .... ~80 l-, 38 N65,40E ~,~--- 8658---50~~-6'956~'57 ........ 690 l"; 27 N68,80E I' 9024-'5t .... ~ ....7t9~;-t9 "7t27,89 N68,50E ~ 978~'50"-'48 ..... '766~;48' 7607, .... 9970----49~4--~8t~80 ..... ~r.6,50' NTO 40E ,:? .... t 035i--'4~--5~03tw'53 ..... 7976"~ 23" N71 'OOE . ', i 054 ~"-46'---54 .... 8t 59'-;'46 8104, i 6 N71 , 50E .~; r ................................. ~'~ :; / · , ~ RECORD OF SURVEY TOTAL COORDINATES 321.19 !{ 509.23 S80,02 N 597,44 459,06 N 711,38 593,67 N 896.99 721,69 t4 1079,82 834,20 N iR47,89 937,95 N i402,00 I005,14 N i503,31 1069,t5 tt t60~,40 1i44,26 N i?27,lg tt~2,74 N i807,86 1274,2i N 1946.45 15~1,88 N 2366,09 ~688,28 14 26~1,12 !875,~8 N 2904,87 ~956.8~ N 2027,67 204~.23 N 2154.49 212t.?0 N 2298.48 2~?0,82 N ~4t4,77 2277.20 N ~686,92 2~86,82 N ~965,22 2490,~ N 4230.4i ~40,29 N 4S65,4.0 2588,75 N 4500,00 2681,76 N 4768.10 ....... DOG LEG - - C L- 0 S--U--R-E -S .......... SEVERITY SECIIOH DISTANCE - ANGLE DE,I,.' I OOFi' DIST~ICE ........ D- - H ~ .......................... 602.-06--..-N---57 45 3t- E ........... 2 708,06 H.57 32 24 E. - 3 846 ,-64----H- 57 - 9--- 54- E ...... 1075,66 I.t 56 30 5 E ........ 1298,79 It-56 t436 E ............... i50i,04 N 56 t4 ~5 E t686,82 N 56 13 i E ...... 1808,~ N 56 13 5~ E E E E E E E E E E E E E E E E E E E E E , ? i 3 ......598 , 095 ? ,'-~3, '68 · , 804 ............... 8.40 ,-?-d ,342 i 066, ,559 - i287,-1 .395 ~ 487, .960 ~67i , ~52 i ?92, t 1927,16- I,!-56- 18 i6-.E .................. ,392 ..... ~-910,-1.7 20'7t ,84 N 562831- E ........ ,550 ;2 ;)54,37 2 t 6~ ,-.87---N---~6- ~5 -- 6- E ....... ,672 ...... 2148.-,-i ~ 2326 43 N 56 47 23 E ,~t~. '"'"08,44 2541 .4i-.-N---~7 ......0 23 ..-E ........~.-71 0 2~-.,..9~ 2818,70 N 57 4 47 E .... ,095 2790,6~ 3109,38-.-N--57 .......6-.-51 E .............. ,i05- 7087.4; 3253.29 H 57 8 40 E ,325 32~0,5';. 3457,65 N 57 9. t3 E ............... ,504 3433,5; 360~,98 N 57 ? 30 E ...... ,2~5 3579,6~ 3757.31 N--57 ..... 5-.-37--E ............ ,-~.77 ........ 37~0-,6~ 392t,93 N 57- t4 57--6 ............2,8[,:S ...... J~95,3'~ .4046.3F 4233,48 N 58 i? 4628.t6-N 58 4908.9~ N 59 3i 5050,72 N 5948 5t91 .50 N 60 .......... .--,- 7 '" .... 53 3,-6 5333,84 N- ......................... ....................... ..... . : SOHIO ~dELL 3.-4i/K-39 SINGLE S,HOT SURVEY JO8 t-t0 COHPUTER- 05 ~,,EC KB ELEY 55,.'30 FT, ~i .......................... ?RUE ~! H EA$-F-DR I P~/ERT'-tCAL ............. SUB DRIFT i,i DEPTH --AftGIiE ......DEPTH SEA DIREC i' 10729---46- 0 0289'26? '$234,37 N73.50E ~ 0918"-44-42 ....... 8422-~49 8S67.t9 N76.00E ,~, i11'00--43-24 8553T3~ 8498.0~ N?O.50E ,~ ii~63-4i--54 8966-v05 e910,75 i471,60E - ~2t8'-'4i .... d ........ 9384-;56- 9329.2G HF2.70E ,~-i2405--4i .... O- 9325~'85 .... 9470.55 N74 60E ..... 125 00---4-0 24---959~TB~ .......9542.57 N75,90[ .,= .... 126-92 '4'~~2-T26 ........ 9686- 98 .... N76.80E i2793 '44 ..... 1'8 ....... 9~15-;'66 '9?60.36 N~'/.30E 12887 -46 ........ 6 --9881--~90"- 9826.60 I,I~7.90E .~, , HE-'FO~t~td~fl~'i~-EXTRflPOL~TED TO' ID .............................................. ~F---BOTTOH--HOL~CLO~URE ..... ~094.-'~0 FEET AT ................. . . b'/! L - ...... RECORD OF SURVEY TOTRL UOOR£ INATES ..... DOG LEG ........ C L-O-S---U--R-E-$ ............SEVERITY ....... SECTION DtSTHHCE --- AHGLE DEG/tOOFT DtST~HCE .............. D- H S ............................ 2722,94 N 2758,31N 2794,76 H 2837.95 H 2879 73 N 2920 37 H 2957 96 H 29~6 O0 H 3012 58 tq 3030 37 t4 4898.73 E 5604.64 N-60 55 57 E .......... ,726 5597,03 5028.44 E 5735.29 H 6! 15 12 E 5149,57 E 5859,-07 H 6t-30 37 E ........... ~,595 - 5271,i8 E 5986,59 N 6i ~2 8 E .059 ~9~2,il 5390,83 E 6ilt 78---~ 61 53.-' ............... .. , ~I-E .4t~ ..... 5511.23 E 62.3'?,16 H 62 4 52 E ........ 56~5,56 E 6S55,8~ ~-6~ t5 5713.,I2 E 6446 66 H 6~' "-' . = 24 25 E .i~o 6444.41 5800,37 E 6536,05 H---62-~3 5~5~.73 E 4596.05 N 62 39 0 E .S943 b59~,~" 047 tq 063.88 t,t 5976 079,65'H "6036 i09,24 H 6t 59 124.79 fl ~227 139, t 1 N 6292 7t 55 E 45 E 46 E 08 E 22 E 3152, !8 N 63 37 t 5 E 5917,8~ E 6666.53.--N--62 -45- 5 E ..............,-920 ........ 6716.14 N 62 6776.65--'N-62---5~ .... t~---E .............. ~.~54 ............ ~7.5~ 6~99,..2~ 6966.7~ 6838.23 H 63 5 31 E ......,692 6899.73---H-63 .... t2 56 E ......... i.582- 696'7.t3 N 63 2'I 8 E .... t,796 7031,79-H'63 29 9 E ........ t,943 7094,60 H-----63 37 t5 E ............... t.900 ~094,-5 6355,88 E SOHIO IJELL 3-4(/K-39 SINGLE SHOT SURVEY JOB NO ~-1188-088 biEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, HEA~URED--- DEPTH COI'tPUTEE- 05 DEC 8,8 K8 ELEV 55.30 FT. TRUE .... VERTICAL'SUB ' HD-TVD DEPTH SEA DIFFERENCE VERTICAL .............................. : .............................................. CORRECTION' ' TOTAL COORDINATES ................................. 0 '0 o ~ i-55 iSS. - .... i O0 ' 0 ' 255 255'-~ ..... RO0 ............. 0 toi ............... 355- 355-. '- :~OO O ~.~. 455 455-: ......... 400 ....... 0" ~.[ 555 555 ~ .... 5 O O O ,~ 655 655'~ ........ 600 ............ 0" ?55 755'-~ ........... 700 0 '~[ 855 855~ - 80 ~;~ ~ 1-055~ ........ tOO ~.~{ ~'55 t't 55: ...... i t 0 ~l ..................... J-SS-~ i ~53-~ t Z 0 :~l -- ~' t-455~ ............. t'4O ~,~ .............. i-556 · ~t ~55'~ ............ t 50 ~ I ......................... I'756 I~5~. ...... I 708 ~l ..... --55 ................ 0 .......... 0 0 0 0 0 ............................ ,- O0---S , O0 --W ,23-11 ................ .-06 E ................................... ........................... . 58--N - I .04'ti .................. .&S.E ............................................. ...... J , 53 . H ............... !-~--P_8 --Id ....................... 2.il N ................. i-,83-W ............................................ ................ 2-. 5i---.H 2.--5.~i ...... W 0 2.7:t-H ................ 3.-t4- W .......................................... 0 ................ 0 ........................... 0 ......................... 2-, 79--H 3 0 ...... 0 ..... 0 -- 2.?J-. N ............ 4 :~6--W ........................................................ 0 ............... 0 ....................... 0 .............................. 2-, 67----N 4:-76- W 0 0 0 - 3.03 N ..............5.35-W ............................................... : .......... 0 ................ 0 ........................... 0 ........................... 4 ~'69"--N 5-r?'I ....... W 0 0 0 8,22 H ...................... 3.9t Id 0 .............. 0 ................. 0 .............................. I I ,.-tg--N .3t .... E ................................. ....... 0 0 i3,76 N .............. 4,~4 E ......................................................... ................ 0 ................................... 0 1 5'~ 93'"-"N 0 0 l?.??' FI ................ I3,54-'E ................ 0 ........................... 0 ............................................ J ~. ~4-'N ...... ~ 8"r J--~.--E ..................................................... · 58-- N ........ 22 ,-98--.E ....................................................... , 60' N ............... 2:'-, 96... E ............................................................. · ~8 tl ...... 3:~, t2-IS .............. .78'-N ................... 38 ,.4~S-E )56 t 955-, ........... t 900 0 ....... 0 ...... 2 t ......................... 2056-~055-, ..... 2000 .... ! I ......... 23 ..... 215~ ..................... 2155. 21 O0 i 0 25 2257 2255-: ............ 2200 ............... 1 ......... O ............... 27 .............. 2357 -P. 355-~ ...... 2300 ..... t .... O ':- 2~.79 N ............... 44,.00-E · i 2457 2455--~ ......... 24'00 ................... 1 ............................. 0 31 . 73-' N ...... 49"r:74-- E ' 2755"~ ............ 2700 2 ..... O .......... 43.15--- N ............ 72-,-.7.9-- E ........... ....................................................... :3~F ................ ~58 ~[, ......... 3 055-~ .............. 3 O O 0 ......... 6 ...................2 6, 4 t 'N - -t4 4-~--~ ................................................... i~'J' 3270 3255-~ ....... '3200 ................... t4 ....................5 96,30---N ...... 162---~-87----E ........................... '[-- 3488 3'455-. ...... 3400 ............... 32 ................. I 0 ....................................... t4 0--,--99--t,I 2-37-:45- E - .... SOHIO OELL 3-41/K-39 HERSURED DEPTH RI,ID OTHER b~TA FOR E',/ERY EVEN TRUE MEASURED VERTtOAL SUB HD-TVD ........... DEPTH DEPTH· SEA DIFFERENCE ......................................... SINGLE SHOT SURVEY JOB NO ~i-1188-008 u~HPUTER- 05 ~:EC 88 i<D ELEV 55,30 PT, lOB FEET OF SUB SEA DEPTH, ~i 3601 3555~--- 3500 - 45 i .................... 37t? 3655,' ;3600 r 3838 3755~ .... 3700 82 ,o~ .............. ~963 3855,-- 3800 i08 II~ '4~95 3955-~ .... 390 O i 39 ,. 4236' 4055. 4000 " ~ 438~ 4t55; ...... 4t00' ' '227 14' ~ ..................... 45~i 4255. 4200 276 ~.~l 46?9 '4355~ ........ 430 O 323 i~; '~ ................ 4824 4455,-- 4400' '[ -4069 4555r .......... 4500 ........ 413 ~',~ ..................... 5t-t-~ 4~55-~ ......4600 457 ' 5-25? VERTICAL CORRECTION --3t 41 47 49 -47 46 -44 44 TOTAL COORDINATES ................... 169.35-N ........ 28i,25 £ .................................. 202,t9 N - 330.42 E ............ 239,47 N ......... 3~6 .~ E ................... 28t.55 N ........ 449.47 E .................... 3~9.07-N ...........521,12 [ 384,08 N 603,-47 E ............................... 445,33--N ............. 692,09-E ........................................................ 503,26 N 78i.i~ E .... -572.76-N ...........868,4-7---E .................................................................. 635.17' N -- 954,$3 ~ .78--.N ........... t.039-,-87 E ............................................................ ,1t N ...... 1t25-,39 E ..... 694 752 ~I 4755~ ........... 4700 501 '~ ............. 5404 .............. 4855'. · 4800 548 ' ? ............ -555'4 4955 ;- ......... 49 0 O 598 --T-s oe ................... soss. 5000 ,~i -5. 862 ..................... 5t55.-- 5100 706 r ~ ............... 60J'6 ............... 5255~ ' 5200 760 ~[ 6-t-68 5355'~ ......... 5300 ....... 812 .~ ................. 6-o~u .................. 5455, 5400 864 ................... 6623 .................. 5655~ 5600 967 ~75' 5'755~ .......... 5700 t 0t9 ~ 692? .................... 5855'," 5800 1 ?080 5955~ ........ 5900 t 124 '-~'_r -~$'~' 4 t 5~-i .......... 6i O0 ....I230 ........ 54 t 66 t '~ 87'---N ~ $6.9 ~-.80 .--[ ................................................ ~[ ...................... ?539 ................ 6255~ ...... 6200 t 283 53 t 724,6~- N ......... 2668',--S6-"E ' ~5-;- .......... ~300 t'33~ "55 ~'787 ~ 25--~ ......... R7~-~5-¢----~ ................................................... ~l ................. ~850 6~5'~ .... 640~ i 3~4 56 1052 .'09 ~a~ 80"08 6555"; ........... 6500 t452 ~655', 6600 I5i2 6755'; 6700 '1574 6855'; 6800 1639 6955~ .......... 6900 ....1700 ......... 44 ................. 810,31 N ..........t2. t-2-.,.-30--[ ........................................................... 47 870,i3 N $30i,32 E ..... 50 ..... 932,98 N ........ 54 997,59 N t49t.?~-E 54 .... ~06t,~4-H ........ t590,~ E ..................... 54 1122,22 N i689,99 E 52 iiSi-~iO---N ......... t-~8~-,-~4---E ........................................................... · 52 - i239.71-N ............ 52 t296,28-N ........... 5i 1354,39- N 5~ t414-,69-.--N .....A~80-~?3-E ......................................................... 52 t475.75H .... 53 i537,36-.--N ........... 2374~?0--E ..................................................................... 52 t599.40 N ........ 247i-~98-.E .......................................................... ,[ ................... 8495 58 ......... t 9 ! 9,46---N .......... 297---t--.--29 --E ................................................... 60 t 988.04-.N ............ ~074-.,.76- E -~ 2058 .-94- N- .ot.-8 ! '~ ......................... 65 - 2t20.95""N .........3296,-84 E 6 t 2 t 70 ',' 25-'N~---74'~'3--~-0'-E SOHIO YELL 3-41/K-39 SINGLE SHOT :.~URVEY HEASURED DEPTH .~ $~i4 7055';--- ..... 7000 "1758 '~i ............ 8973-- 7155, - 7i O0 1818 ..~; 9134 7255~ ........ 7200- 1878 ............. 92~'4 ,:,-- . 7355. - 7300 1938 ,:~ .........9454' 7455-~ - 9400 I ~:~, 96-13 7355 .'- 7500 2057 .,'~ .............. 9'77'~ 7655-7' - 7600 2116 ~- .................. ~9~ ............... ?755 , 7700 2173 ~ t~6~ 7855-~ ........... 7800 ' '2228 ,}~- .............. i'0236 7955-~ .... 7900 228t ,-~ I O~e~ '8055~ ......... 8 000 ...... 2~31 ,~ i-OS~- 8155-, .... St O0 2398 ~ ~6~9 ~255: ...... 8200 ..... 2424 ~ ............... 18823 ................... ~355,- ~300 2467 ~' .......... t096-4 8455; ..... e~O0 250~ z?I - - ~{ ............... i'i-103~ u355'; .... 85ce -2547 ~ ............ 1--1~40 e655---; ..... 860e -2584 z:{ ................... J-J-3~ ~551 .... ~ ~2 ::~:: ................... J- 1-'~'4'9' 8955; ~00 2693 ~/ ...... 1t~t5 .......................... 9t55, 9100 2759 ::~ .................. t2iF~ .................. 5355. ' 9300 2823 ~ .......... 1-23~2 ~455"~ .... ~ 0 O " .................. i 2444 ~555;- 95e~ 2~8~ .................. 5~[ .............................................................. 3V ~ ................................ - .............. ~ ............................... AND OTHER DATA FOR EVERY EVEN 100 '--TRUE' VERT'IC~L"$UB MD-TVD --DEPTH SEA DIFFERENCE 9855: .......... 9608 ...... 2920 9755', .... 9700 2954 9555'~ ....... 9800 ...... 2993 9943','- 9887 3033 ,JOB HO A-1188-008 COHPU'rER- 0.5 DEC 8',:~ I<E ELEV 55.30 FT. FEET OF SUB SEA DEPTH, VERTICAL ............... CORRECTIOH TOTAL 58 60 --60 60 60 59 59 57 55 53 50 47 46 43 ,Ii 39 37 38 36 35 33 33 32 32 33 32 ....... 32 :34 40 ...... 27t2 274t 2766 2';:'95 2826 285,9 29t7 2945 297t 2997 3022 3047 30'70 ......... 309t :3t33 COORDINATES ....................... .... 2214.67--N ..... 3527-~-45'E ........ 2259,87 N .... 36~2-.~5 E ................. -"2305,70--N ...... 3759'~8-E .................... 235t,54 N ....... 3e75:63 E ................................................ 2397.29 N ........ ~991'-,'80 E ................................................... 2442.52 N ..... 4t07,'3a E ...................... 2487.O~-'-H ....... 42~2':"t5"E ............................................. 2529.61 N' 4335.68 E ................. 2569.52'-N ....... 4446--r95--E 2608.78"N ............. 4555-~65'-E 2645,55--N ...... 2680.33 N ..........476~-~85'E ........................................................ .64'-'N-- 4864':5'I .... E ........ .33 H 49~3 '~'~ ~-r E ............................... .49"N ............ 5059~'67 E .............................................................. .39"N 515i,35 E .97-N ......... 5240'~33-'E .................................................................... .30 N .... 5328.86 E ,37'-N ....... 54t6-~-'i'S'"~ .............................................. .~2 N- 5502,~7 E ............................................ .ie-H ........ 55e~.40 E ,94 H 5666,99 E .79-N ....... 575t--,.46 E .86 H 5834.40 E ,65 N -59t7-,.63 E .................................................... ,53 H 600t-,-i6.E .4S-N ..... 2---6084-,~--E ........................ .97 H .......... 6t71-,'~4 E .33"-'N .......... ~265-~56'"E ............................................................. 3t52.18 N ........ 6355,e~ E ....................................................... SOHIO ~.dEt. L 3-41/K-39 .SINGLE ·:HOT SURVEY dO8 t.t0 A-i188-008 C 0 i'1P U -ir E R - 0 '.5 t~ i: i..' ,:~ :2, KB ELEV 55,:~0 FT, ~i--'INTERPOLATED-VALUES FOR 'EVEN-1000 FEET OF %' .'- ...................................... TRUE 'i' HEASURED ........... VERTICAL SU6 ~! DEPTH DEPTH - SEA · ~ 0 ......... O. ----55, ............. ieee ............... tOOe. 945. ~OOO- - 2994, ............ ............ ~ ..................... 6000 ........... 5~45. 519o, , ........... ?eeo ................... 5903, 504e, '~i ~oo.o 65~0 -- 6495; . .......... 9000 ................... 7t72, 7tt7, 11,- ................ ---l-O00~ 7~0t, -- -774B. ............... ~-~-o-oo 9~2o, ~o~ t-~976 ............... 9943, 9087 2ti - ..................... ............ 2¢[ I ........................................................ ' t . , ~ [ ...................................... ~.; ..43i- HEASURED DEPTH, - - TOTAL COORDINATES ,00 S 2,65 N 4 22.45 N 25 294,4 2 H 468 ?07,~3 N t058 ltt6,04 N 1679 1505,16 t-I 2324 t9i6,05 H 2966, 2267,47 N 3662, 2547,99 i.t 277;~,.39 H 2988,73 N 3152, 18 N _. 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',. ~7) '/~v~ ' '53)., 't3~f3.-" 89~'~'~': 'i~!~ /"" '~'? ~5~ · ... , . ~8) I]~g .... 54.) "/~u 90) /~z°' ~,"]26) 19) , /3,39~, 55) ,'1'}'5~'~''. ...' .. ' ~) ' '._ l'3~i. '" .' .q~:'~",,. ~127~._ ZO) /~3Ko 56) 133'~ .J923 13~zz ,,, ~, .' ,A?8). ., ~ ~ -..~ . , : · · .... 26) 13~5A ,.. 62.J "/~.57Z .983 1.3~2~ 13%) ' 28), 1335g 64J' ' I=)~.Y' ' ..: !00). 29) /3 3S?' 65~: 1339ff ~0~) 1~'~1" lq75' ....... - - - ~ ,,..~ ,, , , , . ~ ~ .... .-. I ~.~, 7 ~ .- , . .' ,.. ~ . ~ ' . ~) 3'gO 661 . ~ 102l_ I~'W.~'~' , 3t)' '13~6! 67) 133f1. ]03~ /~W~. _.J ~a~ 32~', "J].3~2 68). ,~,3'3~, ", ..,'_]0~). 33') '~, 133~3 : 69) . I ~)~9...:..;~. ..]o5) ........ 34) , / ~3~.~ ,, , 70) .13¢~'"'::; 106) ,,"'3 "':'*:'::" ' 35) . /3~. 71),~ J ~Pl' ,j 107) 'J~7 1433 I ...... . .... .,~, , - .· . . t36) 135~g 72) lJ~..,'.' <:...)lO8) ,,:1~~ .. ..... .. 144) A _22) ' 2_~ ) ., . · 3_3): , 3_5) I ~l ?.z 92) _t~) 144) PAGE 1 of LOG LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) / , CFD (compensated formation density) BHC/SL ' ' (borehole compensate~t sonic) ~. · . LSS (long spaced sonic) .. SSS (short spaced sonic) CYB (cyberlook) GCT (groscopic survey) DIPMETER SAMPLES: Require~i yes r~oi 'Comments: Date Received: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 15, 1989 John Boyle .. Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the open hole well logs run in the following Endicott wells' WELL 2-70/U-15 *GCT GYRO DIRECTIONAL SURVEY 0.0'- 12118' Run No. 2 WELL 2-42/P-13 *GYRO DIRECTIONAL SURVEY (GCT) 0.0' - 12212' Run No. 2 WELL 3-41/K-39 *GCT Gyro Survey 0.0' - 13640' Run No. 1 Logged by Schlumberger. Sincerely, G~ard' GND/gjr Standard Alaska ~'~ Production Company 900 East Benson Bouleva~rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION January 17, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the open hole well logs mn in the following Endicott well: Endicott Well 3-41/K-39 *Dual Induction Laterolog Run Date: 12-31-88 Run No. 1 13018'-13752' Company: Gearhart *Compensated Density Compensated Neutron Log Run Date: 12-31-88 Run No. 1 13018'-13752' Company: Gearhart Received by: Date Sincerely, A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company ' - 900 East Benson Boulevaro: P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) .564-51 I 1 STANDARD ALASKA PRODUCTION January 17, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one L.I.S. (data format) tape and computer read-out sheet for the open hole mn in the following Endicott wells: 2-42/P-13 3-41/K-39 2-16/M- 16 (CORRECTED) 50 029 21892 5O O29 51878 50 029 21885 Please note tha~-16 is a corrected tape and should replace current L.I.S. tape on file for 3-41/M-16. 9 19Rq "-'"AJasIGI.I:)il & Gas Cons. Commission Date '' Anchorage G~dSincerely' A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska /' " Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 564-511 I STANDARD ALASKA PRODUCTION january 16, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs mn in the following Endicott well: WELL 2-42/P- 13 *Cement Bond Log 10760'-12250' Run No. 1 *Cement Evaluation Log 10760'-12270' Run No. 1 *TPC PositioningIJB G. Ring/Packer 11140'- 11900' Run No. 1 Schlumberger WELL 3-41/K-39 *Cement Bond Log 11300'-13654' Run No. 1 · *Cement Evaluation LOg 11300'-13678' Run No. 1 Schlumberger Received By~ ~ Oil, & Gas Cons. CommL ,ion - ,..~ ~omge Dam Sincerely, Grego/afi~llard A unit of the original Standard Oil Co,npony Founded in Cleveland. Ohio, in 1870. ../ Jij ! ! Ex=ende~ Page 2,1 NOU i2 ~88 09:50 SDI RIG ? 44? P~ll C~e~al Houeek~pln~~~~.~ ...... &~ulI Oba~e ~r~au~e~. p~i~ Opper , s . Kill Lln~ Valves No. flange~~~_ --__ · . , .... RFI F i V__ED ~i~,;r~.io~ 0 K ~ NOV 1 .~ 1988 I -~/~ =~ - Operator '/c~.. laska Oil .& Gas Cons. Commission cc -~upervi;or Inmpeccor '~ Anchorage 1,1 October 31, 1988 Telecopy: (907)276-7542 Ted Stagg Prudhoe Bay Unit Drilling Engineering Supervisor Standard Alaska Production Company P.O. Box 196612 A~chorage, Alaska 99519-6612 Re: Duck island/Endicott 3-41/K-39 Standard Alaska Production Company Permit No. 88-126 Sur. Loc. 2504'SNL, 650'WEL, Sec. 8, TllN, R17E, UM. Btmhole Loc. 4444~SNL, 4386'WEL, Sec. 3, TllN, R17E, UM. Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled.. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ tr~A~ ypu~s, / z C. V. Chatterton Chair~mn of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COb'.~ISSION dlf Enclosure cc: Department of Fish'& Game, Habitat Section w/o encl. ~e · f Environmental Conservation w/o encl. Department o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill F'lllb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil I--I Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company RTE = 56 feet Endicott Field/Endicott Pool §. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47503 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2504' SNL, 650' WEL, SEC. 8, T11N, R17E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 4530' SNL, 4560' WEL, SEC. 3, T11N, R17E 3-41/K-39 KOO683449-G-14 At total depth 9. Approximate spud date Amount 4444'SNL, 4386' WEL, SEC. 3, T11N, R17E November3, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandmVD) property line ADL 312834 4560 feet 3-39 @ 10 feet 2560 13658'MD 10406' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) KicKott depth 2550 feet Maximum hole un,tie 48 o Maximum surface 3693 psig At total depth (TVD) 10300 5032 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 105 Surface 161' 161' Drive 17-1/2" 13-3/8" 68# NT80 Butt 2444 Surface 2500' 2500' 4185 cu ft Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 10756 Surface 10812' 8500' 320 cu ft Permafrost C 12-1/4" 9-5/8" 47# NT951-1 NSCC 2271 10812' 8500' 13083' 10021' 575 cu~'Class G 8-1/2" 7" 29# SMl10 Butt 825 12833' 9854' 13658' 10406' 300 cuft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVE-D S u rface Intermediate OCT 2 1 ]988 Production Liner ~[;::;[<a Oil & ~aS Cons. C0mm[~icm. Perforation depth: measured ',,,~. Ar~chcr~!~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program E'l Drilling fluid pro~lram [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ~t~h~foregoing~_~,,~. is true and correct to the best of my knowledge //,,Z~ /dp.~///////~ Signed Title Endicott Drilling Engineering Supervisor Date ( /~"- Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~-/2_~' 15°'°'g~- 2--/g' ?<~ I 10/31/88 Ifor other requirements Conditions of approval Samples req~d [] Yes ~['NO Mud Icg required [] Yes ~]"No Hydrogen sulfide measures [] Yes ~ No Directional survey requlrec~ ~tg:rYes [] No Required ~~~~ [~/~ workin sure r B 2M' 3M; 5M; I-I10M; [-115M; Other: by order of Approved by ~ Commissioner tne commission Ddt Form 10-401 Re~. Submit ii icate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-41/K-39 (SDI) Objective Well 3-41/K-39 will be drilled as an water injection well. Zone 2A is the primary objective. The completion will be run at the time of drilling. Operation Execute a rig move from slot 4-28 to slot 3-41 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., NT-80 CYHE Buttress Casing to surface. Pressure test casing. Install BOPE. Estimated malimum BHP is 5032 psi at 10300 ft. TVDss. Maximum possible surface pressure is 3693 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 2550 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47g/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill and core 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, SM-110 buttress (TKC) liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaCI packer fluid. Run CET/ CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Continue with CBT into the 9-5/8" casing to the top of cement behind the 9-5/8" casing. Perforate well underbalanced using guns run on drill pipe. Kill well and complete with a simple completion. Perform MIT on completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Note: Notify Alaska Oil and Gas Conservation Commission prior to pressure testing casing, production liner, liner lap, MIT. JWB/10-3-88 and perf ' 2 ENDICOTT PR,OPOSED DIAGRAM WELL 3-41/K-39 (S01) NON-FREEZING FLUID TVD (BKB) MD {BKB) 30" DRIVE PIPE '- 161 FT 161 FT BASE PERMAFROST 1466 FT 1466 FT SSSV 1600 FT 1600 FT . TOP OF DOWN SQUFFTF: CEMENT (ESTIMATED) 2000 FT 13-3/8" 68#/FT N80 CYHE BUTT 2500 FT 2500 FT KOP ( DIR: N 63.62° E; ANGLE: 47.96 ° ) 2550 FT BO'I-I'OM OF DOWN SCX.IEEZE CEMENT (ESTIMATED) 3000 FT 5-1/2", 17.0#/FT L-80 BUTT TUBING W/ 4-1/2" TAILPIPE 9-5/8" 47#/FT NT80S NSCC TOP OF 9-5/8" CEMENT 8500 FT 10812 FT (ESTIMATED) 11283 FT 5-1/2" SLIDING SLEEVE 9-5/8" PACKER 7" LINER TOP 9-5/8" 47#/FT NT95HS NSCC PLUG BACK TD 7" 29#/FT SM-110 BUTT LINER 9820 FT 12783 FT 9853 FT 12833 FT 10021 FT 13083 FT 13579 FT 10406 FT 13658 FT JWB/10-3-88 B.O.P. STACK CONFIGURATION I 3-S/8 IN. TRIPLE RAM STACK 5000 PSI 'WP DRILLING I I ANNULAR PREVENTER I I PIPE RAMS I I 1 8L IND RAMS I I DRILLING SPOOL 2 IN. KILL LINE I GATE GATE I 4 IN. CHOKE LINE GATE GATE PIPE RAMS DRW NO. 116- 85 SHEET I of IO REV. 0 PLAT OF PROPOSED WELL LOCATIONS MPI Wells Located In Sec. SG, T.I?.N.,R.IGE.,Umia! M. SDI Wells Located In Se'c. 8,T. IIN.,R.17E.~Um'~a! M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. j PREPAREO 8Y F.R. BELL [~ ASSOC. PRUDHOE BAY OFFICE JPRUDHOE BAY, ALASKA DATE: NOV. 13, 1985 SCALE: I"=1 MILE DRAWN 8Y: CHECKED'BY' 8.E. C I 3 5 7 9 II t3 ~5 ~7 19 Z~ Z3,7.5 ~7 ~9 3~ ~,~ 3~5 37 .c~. ooooooooooooo oo ooo 2 4 6 8 I0 12 14 16 18 20222426 0000000000000 Z8 3032. 40 4648 00~44 000(~0 F.R. BELL & ASSOC. PRUDHoE BAy OFFICE PRUDHOE BAY, ALASK,i DATE: NOV. 13, lei 5 ICAL[. I', lO' DRW. NO. 116-85 SHEET ? of I0 REV,. 0 0 IflClicetes well I~tdicetel Celceleted SectieACerAer PL 4 T OF SDI PROPosED WELL LOCATED INIEC. e, T.I~., R LOCATIONS · ~ e. UU~T ~. PREPARED FOR SOHIo ALASKA PETROLEUM CO. W(L.L ~kSP ZONE 3 YTb .j,~ 6 L~TZTU~ L.O& .... ~ ~ Y'-S~709'~.47' ~- 7~0~i70.e~ 70~9'20.2409' ~4~'4~.2799' 2~3~. 1- 270163.80 E- 467~41.06 2 Y- 5~70796.40 N- 7801819.43 70~X9'18.~842' 147G51'48,61'0~' 2703.73 8~.'60 X- 27019Z.~7 E- 467547.32 ~ y- ~97o~ '~s i~-'TeoseTi '2~ 7o~s~'2o 2D42"" i47'c~1'4B 990~:' ', 2:33 4 Y' ~707~7.44 ~N' 7S~X~--~.e0 70~1~'1~.~7~" ~47~'4~,~21~" 2702.~ ~ ~ Y= ~70~67,~6 tN= 790~B7~,5~ 70~1~'20,2b~' ~ ~47~ ~'49.70~6" 2~2.~ x- 270~a~.6~ E- 467~47.~ 6 Y- 5970798.49 ~- 780~B~0.~7 ~0~'1'9'~8'.610B" 147~m~ '4e.0~2~" 27'0t.02 ~- 270201.46 E- 467~53.37 7 Y" 5V70~68.60 M, '780187'~."~5 70~'20.2808" t47oS~'4~:'At24" 253~.23 848.3t-'- X- 270~9].64 ~- 467~0. t3 8 Y- ~970799.54 N-'TaOt820.54 70b19;"lg,6240"''~'47c~l'47,7429" 2699,67 825.86 x- 270211.41 E- 4675~6.39 9 Y-'5970969.65 Ns"Tu01872:3~ 70'~19'26,'2940" 147~'48.t2~2" 2~29.87 0~8.4'0" X- 27020s.~e E- 467~53.16 t0 Y- 5970800.58 N' 7801820:'90 70°19:'10.6~7~" 147°51'4'~.4537' 26~8.~2 X- 270221.35 E- 467~59.42 11 Y= 5970970.69 N- 78'01872.69 70°19'20.307~" ~7c5t"47.8340" 2~2e;~2 828.49 x, 2702~3.~3 E- 4673~6.18 12 Y-5970801.63 N-7801821.27 70~19'18.6506" 147~1'47.164~"' 2696.~7 oO6.o4 x, 27023~.30 E- 467562.44 13 Y, ~970971.74 H. %80187~.06 70~19'20.~206· 147~1".47.5448. 2~27.17 '818.~7 X- 270223.47 K- 467~9.2~ ......... i4 Y- 5970802.67 N- 7801821.64 70o19'18.6639" ~47~51'46.8754" 269~.62 796.13 X- 27024~.24 E- 467565.47 1'5 'Y- 5970972.79 N- 7801873.43 70'~29'20.~e" 147°~1'47.2~6" 2~2'~;e2 808.66 X- 270233.42 E- 467562.23 '~6"'Y- 5~70803.72 N- 7801822.01 70~'t8.677~; 147°5~'46.3862" 2694.27 786.2t x- 27025t.t~ E- 467568.4~ . 17 Y- 5~70973.8~ M- 7801873.80 70~19-;20.347~" t47o51'46.~664· '2'~2'4.4'7 798.75 x- 270243.36 E- 467~6~.26 18 Y- 5~70804.76 "h- 7801822.3b 70~'18.6~04· 1~0~1'46'.2~70· 2692.~1 7~6.30 X- 27026t.t3 E- 467~7t.~2 l~ Y- 5970~74,88 N- 7801874.1'6 70~'20.3604· 147o~1"4~'.6772· 2~2~.~2 7ee.e~ x- 2702~3.31 E- 467~68.28 20 Y" ~7080~.81 M- 7801822.7~ 70~1'e'~8.7037· j47~1'46.~078'" ' 2'691.~6 766.3~ x, 27027L.08 E- 467~74.54 21 Y- 5~70~75,~2 M- 7801i74.53 70~1~'20.3736" t47o51'46.~880' ~ 252t.76 X- 270263.25 E- 46757t.30 ........... .. ii i ii i i i ii i i ii i i i i ~DI PRO~ED WE~L L~ATI~ ~T ~%%~%~ LOCATED IN SEC 8 T. II N R.17E UMIAT M ~:~9_~_~ .... ~,~ SOHIO ALASKA PETROLEUM v~ ],~ ~1~ ../~-~ '" F.R BELL. & ASSOC ,& ~ss~~ PRUDHOE BAY OFFICE 'OR~w'N 8 y eEv. O PRUOHOE BAY, ALASKA CHECKEO ~ ~ i i i iii i i i Iii 22 Y- 1417010&.15''' #- 710112'~.'i'i 7~lg'il.71&t' 147eli'4S.7186· 2&gt. Zl 71~.'47 X- 270211.0~ .~- 417~77.~ 2~ Y- ~970976.97 N- 7001074.90 70~19 ' 20. 3869' Z47°~I;'46'i*~gB9' 2~2'0.4~ 7&9.01 X- 270273.20 E- 467~74,33 24 ' Y- ~70~07.90 ~-H:-~'BO~'G2-~-:-4e'T~O*~';~,~02~'-~4-7~-~2 4~.4294" ..... 2688.8~ 746.~ x- 270290.97 ' E- 467~80.~9 x= 270~00.91 E= 27 Y= 5970~B2.1~ ,= 7B0187~.74 70~19'20.45~3~-- i47~51'44.~52'~-~ ..... ~5~'~';-~ 719.44 X- 270322.~2 E- 4~7589.45 '. 2a Y= 5970B13.~2 ~- 7,0~25.3~ 70°~9'1,.79~" 147°5~'43.t,35" 2112.10": I~7.00 29 Y- 5970983.24 ~- 7801",77.i~ X- 270552.87 E- 467592.48 I 30 Y" ~970814.17 N" 7BOIB25.i9 70°~9'tB.1098" 14~51'43.&943" 2&10.'7S X' 2703~0.64 E" 467~98.74 3~ Y' ~970984.28 N' 780~877.48 7~9'20.479B~ Z47°~t'44.074~" 2~'~0.'9~ &99.&2 X" 270342,Bt E' 467~9~.~0 32 Y' ~9708~.22 N, 7802826.06 70°i9'~8.B23~" ~47°S1~43.4'0~2" 2679.'40 &77.'Z7 X" 270360.58 E' 46760Z.76 33 Y" ~97098~'33 N"""780~87~.8~ 70°~9'20';493~" 147°~'4'3.78~3' 2~09"."&~~ &Bg. Tt X" 2703~2.76 E' 467~98.~3 34 Y' ~9708~6.26 N' 7802826.43 70c29"[8.8~64" ~47°~2'43.~60" .... 2678.04 : &67.26 X" 270370.~3 E" 467604.79 3~ Y' ~970986.37 N' 7801878.2l 70°19'20.~063' 147°51'43.4961' 2508.25 * &79.79 X' 270362.70 E' 46760~.5~ 36 y, ~970817.31 N, 7801826.80 70~'9'~8.8496' ~47°5~;42.8268' X' 270380.47 E' 467607.8[ 37 Y' 5970987.42 N' 7801878.58 70c~9'20.~96 X' 270372.6~ E' 467604.~8 4 ...... 38 Y- 5970818.35 N- 7801B27.~& 70o19'~8.8629· ~47°5~'42.~37'&' 2675.34 &47.43 X- 270390.42 E- 467610.84 39 Y- 5970988.46 N- 7B01'87B.95 70o~9'20.~329· 147o5~'42.9'~71' 250~34 &Sg.'t7 x- 270382.~9 E- 467607.&0 . , ~ . , 40 Y- 5970819.40 N- 780~827.~3 70o~9'1B.8762' ~47°~1'42.2484' 2673.99 &37.52 X~ 270400.36 E~ 4676~3.86 41 Y- S970989.5~ N- 7801879.32 70o~9'20.~46~'' .... ~47°~1'42.&286'' 2504.~9 &50.05 X- 270392.54 E- 467610.&2 ..... 42 Y- 5970820.44 N- 7801827.90 X- 2704~0.31: E- 4676~6.88~ ... i ii ii i L I iii I I I SDI ~O~SED WELL L~ATION LIST ~~%~ LOCATED IN SEC I T. II N R. ITE UMIAT M ~ ~ - e · -- ~ 4L~t ' ., , ........ ~..~--.~:--a SOHIO ALASKA PETROLEUM CO. % ......... "''~'~ -- ~:'~ DRW. NO. IIG-15 PREPARED BY DATE:NOV. I~ e, ~,:-~ ~-~/~ ~ ~b ~ .~...~..~ ~ SHEET ~k~ss~~ PRUDHOE BAY OF~CE -~%~~ REV. O PRUDHOE ~Y, ALASKA DRAWN BY: R.G.T. CHECKED BY: I.E i iiii i iii ii i ii i ii ii i ii i iii 43 ~1 ~970990.S6 N~ 710xi79.69 70o~9'20.~594· ~4~'42.3394' 2soZ.14 640.:4 I~ 270402.49 E~ 4676x3.6S ~, 44 .... T- 1~70i2S.4, I. 7101121.27 700J9'J'l.9027'' ..... S47°S1'41.67~' 2671.29' 617.69" X' 270420,2~ E' 4676~.9~ 45 Y' 597099:,60 N' 710~180.O&" 70~9'20.5727' ~47~51'42.0~02' 2501~49 630.23' X- 27041-2.43 E- 467616.67 ...+ : X- 2704~0.20 ~ E- 467622.93 ~7 ~-;-~-~7-'~9~:~-~ N~~8'~;~2 -70~;'2~"'.~8~0" ~147~5~'4~.76~0"~ , 2~00. t4 &20.32 ~ X- 270422.38 E- 4676t9.70 t ~: 4~ ~ Y- 597082~ N" 7801~29.0t -70c19'18.9292" T~47c~1'41.0917' ....... 2668.~-~ .... X- 270440.~ E- 46762~.96 49 Y. ~970993.69- N,' 7i01B80.79 70o~9"20.5992-'' ~470~'.41.47t'1· 24'98;7i 610.40 X- 270432.32 E- 467622.72 ~ SO Y- ~970'824.62 N- 780~82'9.37 70C"~9'~8.942~' ~47~5~'4'0.i02~' 2667.23 ~ ~87.96 ~ X, 270430.09 E- 467628.98 i i i iiii ii i iii i i i i i i S DI ~OPOS E O WELL LOCATION LIS T --.~ OF 4( ~- LOCATED IN SEC. 8,T. liN., R. IZE. U,IAT M. ~~ ~ ~ PREPARED FOR ~'"~'~.~~ S O H I O ALASKA PE TROLE U M CO. '~.~.&. ~19~ /~~ DRW. NO. 116-85 PREPARED aY DATE' ~V. 13, l.~.%. //-~~ ......... ~a~o~..~~~4 F.R. BELL & ASSOC '~rss,~~~ s.Ecr ~o~ ~o · SCALE' N/a ~g~~~_ PRUOHOE BAY OFFICE ~N er' e~V, O PRUOHOE BAY, ALASKA __ CHECKED IY: i i i i i i ii i i i i ii i i i i i iii I i ELr '-ti. ID ! I ~u.g 6'r'~T~M ~Ot2L.JL~ THIS IS A ~ PIIIETA~IY OESIGI~ OF nE'PI~ODU~rION USE OF THIS DEIGN IS PEK, Idis~JBIE ONLY AUTHOqD IN ~ BY P.A.~ ... ISSUED FOR INFORMATION ONLY i FElT 5E~-TION ~LE¥&TIONI ~ '~::V~l. 1 F'I~KI , m , MUD :2J¢CW V&L.V~- OV~MT~:~L L. OC~r . _ PILL . [ i THIS IS A PRO- PRtETARY DESIGN OF P.A.A. IIIEPIIOOUC'IION OR U~[ OF THIS DESIGN IS PER. IILLSiSLE ONLY IF AUTHORIZED IN WRmNG BY I I'~ ISSUmD FOR ONlY 13-578" APl-S000, 13-5/8" APl-B000, CONTROL LINE-- 13-3/8" --9-5/8" CONTROL LINE ~-~/2:' F l(;ill~E I WELLI~IEAD ASSEMt3LY.ENDICOTT 5KSI Z_.3.-.7~/8';? 9__:S/a"× ,- ~_/Z" _ __ (3) II. 3. 9-5/8" CASING ,AND tdELI.HEAI) EQIIIPHENT 3.1 TESTING B.O.P. STACK 1. After g.O.P.'s are nippled t,p to :;pllt :;peedhead, make up 13" x 4-1/2 Internal Fl ,J:;l~ Il. (). I'. test pl~:, Accessories Item ?, t'art No. 538116. 2. l.ower plug into head (it t~i 11 land on lower step). Tighten ~ lockscre~,s 90° apart. 3. After B.O.P. test, back out lockscreu:; nnd ret rleve test plug. CAUTION: It Is very important not to have the lockscre~as protruding into the bore of the head =bile either running or pulling the B.O.P. test plug. Airways check them tf in doubt. (2q) SPLIT SPEEDHEAO TEST PLUG 13-3/8" 0.0. C^SII',,IG ACCTESSOR £ES [TEH 6 / II Il {I II II II 2~ 0 I i I ACC~SSOR,[ ES [TEH 7 1 11 Ii II II II ¥ ( ,! 2~0 II. ~. 4-1/2 TUBING AND WELLHEAD E(~UIPHENT t~. I TESTING B.O.P.'s 1. After 9-5/8" has been set and tested, run in B.O.P. test pi,ss, Accessory Item 6, Part Number 538117, ~hich lands In upper bowl of the split speedhead. RtJ~ in 4 Iockscrews lightly, 90° apart to keep plug from moving. 2. After test, retract lockscre~ts and pull 3. Run in short bowl protector, Accessory item 8, Parc Number 538114, using the same running tool, Accessory Item 5, Part Number 538115, that was used for the lon~ protector. 4. After bowl protector is in place, run In 4 lockscrews ltghtly to hold protector in place. CAUTION: Upper lockscreus must be retracted ~hen the bo~l protector or B.O.P. test plug is either run or pulled. I I 3 - TEST PLUG --PACKING PORT TEST PORT --LOCKSCREW CASING HANGER --SPLIT SPEEOHEAD o.. . ENDICOTT DEVELOPMENT WELL 3-41/K-39 ($DI) SLOT 3-41 SURFACE LOCATION X = 270,393 FT ; Y = 5,970,990 FT 2504 FT SNL; 650 FT WEL SEC8, T11N, R17E DEPARTURE TO BHL: 7583 FT 13658 FT MD 10406 FT TVD BKB TRUE GRID N 63.62°E DEPARTURE TO TARGET: 7389 FT 13397 'FT MD 10231 FT TVD BKB NOTE: THE NEAREST WELL TO 3-41/K-39 IS 3-39/J-39 LOCATED 10 FT WEST AT SLOT 3-39. JWB/10-17-88 $1$DUA10:[DRAN017]$IK39 CLOSAP SHORT.LIS;5 Search Radius= 200 COURSE LINE For proposed well: 3-41/K-39 [14- 3-11-17] Location = W-E S-N TVD(SBS) Top 270393.00 5970990.00 -56.00 Bottom 277299.80 5974120.12 10350.00 Note: All depths in feet Below Kelly Bushing (BKB) 17-OCT-1988 15:28 --- Closest Approach Analysis --- Date: 17-OCT-88 Time: 15:28:08 Page 1 Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000025 SI-25 A000-0000026 SI-26 A000-0000028 SI-28 A029-2028000 SI-DI1 A029-2028001 SI-DI2 A029-2156900 ;,.(.) _";- ! $I-M33 A029-2162400 SI-O29 A029-2164000 SI-T34 A029-2164001 SI-M35 A029-21~64500 SI-N32 A029-2166800 SI-K37 A029-2169200 SI-P27 A029-2170100 $I-L36 A029-2171400 SI-L34 A029-2172300 SI-Q32 A029-2173100 SI-P38 A029-2173500 $I-J40 A029-2175100 SI-K33 A029-2176400 SI-J39 A029-2178000 SI-L28 A029-2181100 SI-M39 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 3427.0 174.5 3710.7 1039.9 1196.9 7186.9 4012.3 7693.9 5001.4 753.1 ]')51.[ 36.~ 295].2 [7.2 2550 U 2749 7 1 9 101 9 2550 0 0 6 0 7 0 6 2100 5 0 9 2550 0 800 9 100 8 0 7 2550 0 235 8 0 0 8 7 0 0 0 0 0 0 0 0 0 0 0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2550.1 2762.8 0.0 100.0 2550.0 0.0 0.0 0.0 2099.6 00 2549 6 800 0 100 0 O0 2549 5 235 1 11.6 60.0 76.2 153.4 0.0 221.6 0.2 221.6 6.9 114.8 0.0 41.3 0.0 263.8 0.0 31.3 11.2 126.9 0.0 271.5 2.0 169.3 4.9 36.6 0.2 161.0 0.0 10.2 5.0 189.9 4 .2 18.5 Vertical Intersection /PROPOSED\ /NEARBY% TVD DEPART TVD DEPART VERTICAL DISTANCE 5779.2 2451.0 6870.2 3931.8 1118.7 / 2958.1 16.9 2749.7 L3. [ -208.0 4095.6 599.7 4317.1 582.0 222.2 5956.2 2647.3 6624.9 2629.6 669.4 $15DUA10:[DRAN017]SIK39 CLOSAP SHORT.LIS;5 A029-2183500 51-O34 2550.0 0.0 2551.3 A029-2184800 SI-M30 0.9 0.0 0.0 SUMMARY The well which comes closest to the proposed well is: A029-2156900 SI-Q35 Closest approach distance = KICK OFF for this run = 5.3 feet 2550.0 feet 13.2 0.0 189.9 180.0 17-OCT-1958 15:28 Page 2 $1$DUA10:[DRAN017]SIK39 CLOSAP SHORT7.LIS;4 Search Radius= 200 7 DEGREE LEAD LINE For proposed well: 3-41/K-39 [14- 3-11-17] Location = W-E S-N TVD(SBS) Top 270393.00 5970990.00 -56.00 Bottom 276866.85 5974938.52 10350.00 Note: Ail depths in feet Below Kelly Bushing (BKB) 17-OCT-1988 15:29 --- Closest Approach Analysis --- Date: 17-OCT-88 Time: 15:29:07 Page 1 Closest Approach WELL IDENT /PROPOSED\ /NEARBY~ CLOSEST TVD DEPART TVD DEPART DISTANCE A000-0000025 SI-25 A000-0000026 SI-26 A000-0000028 SI-28 A029-2028000 SI-DI1 A029-2028001 SI-DI2 A029-2156900 $I-M33 A029-2162400 SI-O29 A029-2164000 SI-T34 A029-2164001 $I-M35 A029-2164500 $I-N32 A029-2166800 SI-K37 A029-2169200 $I-P27 A029-2170100 $I-L36 A029-2171400 SI-L34 A029-2172300 $I-Q32 A029-2173100 SI-P38 A029-2173500 SI-340 A029-2175100 $I-K33 A029-2176400 SI-J39 A029-2178000 SI-L28 A029-2181100 SI-M39 A029-2183500 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 3333.9 138.2 3624.0 1015.6 1210.2 7521.7 4383.8 8025.6 5365.1 741.0 ~'],i0.5 ]7.3 2959.8 L7.5 0.9 2550 0 2749 7 1 9 101 9 2550 0 0 6 0 7 0 6 2100 5 0 9 2550 0 800 9 100 8 0 7 2550 0 235 8 0.0 8.7 0.0 0.0 0.0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2550 2762 00 100 0 2550 0 00 00 00 2099.6 00 2549 6 800 0 100 0 O0 2549 5 235 1 11 .6 76.2 0 0 0 2 6 9 0 0 0 0 0 0 11 2 0 0 2 0 4 9 0 2 0 0 5 0 4 2 60 .0 153 .3 221.6 221.6 114.8 41.3 263.8 31.3 126.9 271 5 169 3 36 6 161 0 10 2 189 9 18 5 Vertical Intersection /PROPOSED~ /NEARBY~ TVD DEPART TVD DEPART ,, 2958 .9 ]7.0 29]2. [ L~, .5 %[ I !.5 ;7.', %.* ;%. ~ '3~. VERTICAL DISTANCE -26. 2 13L.5 5639.2 2295.7 6142.8 2305.2 504.3 $1$DUA10:[DRAN017]SIK39 CLOSAP SHORT7.LIS;4 SI-O34 2550.0 0.0 2551.3 13.2 189.9 A029-2184800 SI-M30 0.9 0.0 0.0 0.0 180.0 SUMMARY The well which comes closest to the proposed well A029-2156900 SI-Q35 Closest approach distance = 0.9 feet KICK OFF for this run = 2550.0 feet is: 17-OCT-1988 15:29 Page 2 Interval Mud Weight ENDICOTT MUD PROGRAM SATELLITE DRILLING ISLAND WELL 3-41/K-39 Viscosity Fluid Loss (sec/qt) (ml/30min) pH 0-2,500 8.8-9.8 100-200 20-15 8.5-9.0 9.2-10.2 9.6-10.2 2,500- 13,083 13,083- 13,659 Set 13-3/8" casing 40-45 "15-16 9.5-10..0 Set 9-5/8" casing 40-45 6-8 9.0-10..0 Hang 7" Liner Mud Type/ Components Generic Mud #5 Seawater Fresh water Gel Soda Ash Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill Bland Coring Mud Seawater Fresh water Gel Drispac Sodium Polyacrylate Citric Acid Blend Calcium Carbonate POOL ARCTIC ALASKA RIG NO. 7 MUD AND SOLIDS CONTROL E~UIPMENT Equipment Manufacturer Model Nominal Capacity Shaker Brandt Dual Double 1000 gpm Desanders Tri Flow/Pioneer Mann-Design 2 each - TFI-126 screens 4 each - Pioneer 12" Economaster Cones I000 gpm (each) Mudcleaners Brandt Double 8 each - 4" Cones 400 gpm (each) Centrifuge Oiltools Decanting, Type S-3-0 160 gpm Degasser SWACO Vacuum 1000 gpm Agitators Brandt 7 each- 5 h.p., 32" Impellers Hoppers Geosource 2 each - 1000 gpm S-800 Sidewinders The trip tank and mud tank sections each have one vertical pit level float indicator which are connected to the drilling recorder system that contains visual and audio warning devices located in the driller's console. MISC44:00027 ~-h POOL ARCTIC ALASKA RIG NO. 7 Mud Tank/Trip Tank Monit, orin~]-Recordin~ TOTCO, PITOMETER UNIT L-8 (PNEUMATIC) DRILLING RECORDER SYSTEM TOTCO, MODEL ~R8WPT (E) RS (2) F DRILLER'S CONSOLE TOTCO "COMMAND" CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE ·DATE )-See ,fc i 1. zs (2 thru 8) (8) ' (9 thru 13) i0. (10 amd 13) 12. 13. (14 thru 22) (5) BOPE (23 thru 28) (29 thru 31) (6) Add: Geology: EnB~neering: LCS -~ BEW /' my: 08/11/88 ~.01i Company J~. ~ Lease & Well No. · " YES NO the permit fee attached .......................................... ~., --. 2. Is well to be located in a defined pool ............................ ~ ~. 3. Is weil located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~fC ....... 5. Is sufficient undedicated acreage available in this pool ............ ~f~ ,,, 6. Is well to be deviated and is wellbore plat included . .............. ~;M~. 7. Is operator the only affected party .................. ". ........ ~ , 8. Can permit be approved before fifteen-day-wait 1] ....... [ .... 11 ._ i , 14. 15. 16. 17. 18. 19. 20. 21. · 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. Does operator have a bond in force .................................. Isa conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ ....... Does the well have a unique name and number ........................ ~g~ ,, Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~/~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to .Fmm~/~psig .. mply /AP1 (May 84) ' ~ Does ~he choke manifold co w RP-53 ................. Is the presence of H2S gas probable ................................. eXPloratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc.. are survey results of seabed conditions presented 32. Additional requirements ... , , 'INITIAL ''GEO'"''' ' I POOL[ ~.C~. S STATUS AREA Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. 3-41 / K-39 ENDICOTT Run 1' 22 - December - 1994 PDK-1001GR 130O0 HED WESTERN '" ~'"' ATLAS '~,~,-! qb.5¢-~aa.Wireline Services Tape Subfiie 2 is type: LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 3-41/K-39 500292187800 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 29-DEC-94 5906.04 K. BRUNNER J. POWERS 8 11N 17E 2504 65O 55.30 55.30 14.50 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 13.375 2505.0 68.00 9.625 13023.0 47.00 7.000 13760.0 29.00 5.500 12848.0 17.00 GRCH 13018.5 13028.5 13057.5 13065.0 13073.5 13076.0 13083.0 13093.0 13106.0 13107.0 13114.5 13115.0 13115.5 BASELINE DEPTH 13016.5 13025.5 13057.5 13065.0 13072.5 13074.5 13082.0 13091.0 13104.5 13105.5 13114.0 13114.5 13115.5 EQUIVALENT UNSHIFTED DEPTH - DLL GR 2 1 31-DEC-88 UNKNOWN PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS 1312O.5' 13125.0 13129.0 13135.5 13136.5 13148.5 13149.5 13155.0 13157.0 13159.5 13165.5 13170.0 13176.5 13180.5 13185.0 13189.0 13190.0 13191.0 13198.0 13204.0 13208.0 13217.0 13217.5 13227.5 13228.5 13230.0 13230.5 13250.0 13261.5 13311.0 13352.0 13404.5 13424.0 13455.0 13456.5 13482.5 13499.5 13503.5 13504.5 $ REMARKS: 13122.0 13127.0 13130.5 13135.5 13136.0 13148.0 13148.5 13154.0 13156.5 13158.5 13165.0 13169.5 13175.5 13179.5 13185.0 13189.0 13189.5 13190.5 13199.5 13203.5 13207.0 13216.0 13217.0 13227.0 13227.5 13229.5 13230.0 13249.0 13260.5 13312.0 13351.5 13404.5 13423.0 13454.5 13456.0 13482.5 13499.5 13504.0 13505.0 PDK-iOO/GR. LOG TIED TO CET DATED 05-JAN-89. WELL IS A WATER INJECTION WELL. SHUT-IN WHILE LOGGING. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL 3 PASSES. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 25,000 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL 3 PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. / ? ?MATCHIA. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12988.0 13000.0 BASELINE DEPTH 13016.5 13025.5 13057.5 13064.5 13072.5 13074.5 13082.0 13091.0 13096.0 13104.5 13105.5 13114.0 13114.5 13115.5 13120.5 13125.0 13129.0 13133.0 13135.5 13138.0 13148.5 13149.5 13155.0 13157.0 13159.5 13163.5 13166.0 13170.0 13176.5 13180.5 13185.0 13189.0 13190.0 13191.0 13195.0 13198.0 13204.0 13208.5 13217.0 STOP DEPTH 13588.0 13600.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... SGMA 13018.5 13028.5 13057.5 13064.5 13073.5 13076.0 13083.0 13093.0 13099.0 13106.0 13107.0 13114.5 13115.0 13115.5 13122.0 13127.0 13130.5 13133.0 13135.5 13138.0 13148.0 13148.5 13154.0 13156.5 13158.5 13163.5 13165.5 13169.5 13175.5 13179.5 13185.0 13189.0 13189.5 13190.5 13195.5 13199.5 13204.0 13208.0 13216.0 13217.5 13227.5 13228.5 13230.0 13230.5 13250.0 13261.5 13311.0 13352.0 13404.5 13424.0 13455.0 13456.5 13469.5 13482.5 13499.5 13503.5 13507.5 13525.5 $ REMARKS: 13217.0 13227.0 13227.5 13229.5 13230.0 13249.0 13260.5 13312.0 13351.5 13404.5 13423.5 13454.5 13456.0 13470.0 13482.5 13499.5 13504.0 13507.5 13525.5 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 i CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 i 14 SGMB PDK 68 I CU 15 SGNT PDK 68 i CU 16 PHI PDK 68 i PU-S * DATA RECORD (TYPES 0) Total Data Records: 94 958 BYTES * 4 4 4 64 00 201 24 00 201 24 00 201 24 Tape File Start Depth = 13620.000000 Tape File End Depth = 12965.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22288 datums Tape Subfile: 2 314 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12988.0 13000.0 STOP DEPTH 13588.0 13600.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 12991.5 12992.0 13003.0 13004.0 13012.0 13013.0 13013.0 13014.5 13014.5 13017.0 13015.0 13016.5 13015.5 13017.5 13020.5 13023.0 13025.0 13027.5 13027.5 13030.5 13029.0 13031.5 13030.0 13032.0 13030.5 13033.5 13031.5 13034.0 13033.5 13035.5 13047.0 13048.0 13049.0 13050.0 13050.0 13050.5 13051.0 13051.5 13053.0 13053.0 13053.5 13054.0 13054.5 13055.0 13055.5 13055.5 13060.5 13061.0 13066.0 13066.0 13066.0 13072.5 13073.5 13076.5 13078.0 13080.0 13081.0 13081.0 13082.0 13081.5 13083.0 13084.5 13086.0 13085.0 13087.0 13085.5 13087.0 13091.0 13092.5 13091.5 13093.5 13097.0 13099.5 13099.5 13100.5 EQUIVALENT UNSHIFTED DEPTH SGMA 13100.5 13101.5 13102.0 13102.5 13103.0 13104.0 13104.5 13105.5 13119.5 13120.0 13121.0 13125.0 13125.5 13130.5 13135.5 13136.0 13136.5 13137.0 13140.0 13140.5 13143.5 13144.5 13145.5 13146.5 13158.5 13159.0 13159.5 13175.0 13176.0 13180.5 13182.5 13183.5 13184.0 13190.0 13192.0 13192.5 13193.0 13195.0 13195.5 13197.0 13199.5 13202.5 13203.5 13204.0 13207.5 13208.0 13208.5 13209.0 13209.5 13217.0 13217.5 13228.0 13228.5 13249.5 13250.5 13262.0 13267.5 13268.0 13270.0 13271.0 13101.0 13104.5 13106.0 13106.5 13120.5 13121.5 13126.5 13135.5 13136.0 13136.5 13139.0 13145.5 13157.5 13158.5 13180.0 13182.5 13190.0 13193.5 13196.5 13203.5 13204.0 13207.0 13207.5 13208.0 13216.0 13217.0 13227.5 13249.5 13266.5 13267.5 13269.5 13270.0 13103.0 13103.5 13104.0 13105.5 13106.0 13106.5 13107.0 13122.0 13122.5 13127.0 13131.0 13136.0 13136.5 13140.5 13143.0 13144.0 13144.5 13158.0 13159.0 13174.5 13175.0 13179.5 13183.0 13184.0 13192.0 13193.0 13194.0 13195.5 13198.0 13200.5 13203.0 13203.5 13208.5 13209.0 13228.0 13248.5 13261.0 13272. 13287. 13311. 13315. 13347. 13350. 13366. 13368. 13379. 13398. 13405. 13410. 13412. 13413. 13415. 13416. 13426. 13429. 13430. 13433. 13446. 13447. 13450. 13454. 13455. 13456. 13460. 13462. 13463. 13464. 13464. 13467. 13467. 13470. 13471. 13475. 13476. 13476. 13478. 13478. 13487. 13494. 13495. 13496. 13504. 13529. 13535. 13536. 13545. 13546. 13551. 13551. 13559. 13561. 13562. 13571. 13573. 13574. 13577. 13578. 5 5 0 5 5 0 0 0 5 0 0 5 5 5 5 5 5 0 0 0 5 5 5 5 5 5 0 0 5 0 5 0 5 5 5 5 0 5 0 5 0 0 5 0 5 0 5 5 0 0 0 5 5 0 0 0 5 0 5 0 13271.5 13288.0 13311.5 13347.5 13350.0 13365.5 13367.5 13379.5 13410.0 13412.0 13412.5 13425.5 13432.5 13446.0 13446.5 13449.5 13454.5 13455.5 13456.0 13475.0 13475.5 13476.0 13477.5 13478.5 13487.0 13493.5 13495.0 13496.0 13504.5 13529.5 13545.5 13546.0 13551.0 13552.0 13561.5 13562.0 13573.5 13574.5 13316.0 13398.5 13405.0 13415.5 13416.0 13428.5 13429.0 13454.0 13459.5 13462.0 13463.5 13464.0 13464.5 13467.0 13468.0 13471.0 13471.5 13535.5 13536.0 13559.5 13571.0 13576.5 13577.0 13594.5 $ REMARKS. ' 13595.0 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ? ?MATCH2 B. OUT $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code SamPles Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 O0 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 mmmmmmm 64 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 94 Tape File Start Depth = 13620.000000 Tape File End Depth = 12965.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22288 datums Tape Subfile: 3 286 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 12988.0 13000.0 STOP DEPTH 13588.0 13600.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 12991.5 12992.0 13003.0 13004.0 13012.0 13014.0 13015.0 13017.5 13016.0 13018.0 13028.5 13031.5 13029.0 13032.5 13029.5 13032.0 13030.5 13034.0 13032.5 13032.0 13034.0 13033.0 13034.5 13034.0 13035.5 13049.0 13050.0 13050.0 13050.5 13051.0 13051.0 13051.5 13051.5 13052.5 13052.0 13053.5 13054.5 13054.5 13055.5 13055.5 13056.0 13061.5 13061.0 13062.0 13062.0 13065.5 ' 13066.0 13066.0 13066.0 13080.0 13081.5 13086.5 13088.0 13090.0 13091.5 13091.5 13093.0 13095.0 13098.0 13098.0 13100.0 13100.0 13102.0 13103.0 13101.0 13103.5 13102.0 13104.5 13103.0 13105.0 13103.5 13105.0 13105.5 13107.0 13106.5 13107.5 in separate files. EQUIVALENT UNSHIFTED DEPTH SGMA 13112.5 13114.0 13115.0 13116.0 13119.0 13120.0 13123.5 13124.0 13125.0 13128.0 13131.5 13132.5 13133.5 13135.5 13136.0 13137.0 13139.5 13144.0 13145.0 13146.0 13148.0 13159.0 13159.5 13163.5 13166.5 13167.5 13175.5 13176.5 13177.0 13177.5 13180.5 13182.5 13183.5 13185.5 13189.0 13191.5 13192.5 13193.0 13195.5 13198.0 13198.5 13199.0 13199.5 13202.5 13203.5 13204.0 13208.0 13208.5 13209.0 13209.5 13211.5 13212.5 13215.5 13216.0 13218.0 13218.5 13227.5 13228.0 13228.5 13250.0 13115.0 13115.5 13116.5 13120.5 13125.5 13126.0 13129.0 13135.5 13136.0 13136.5 13139.0 13143.0 13147.0 13158.0 13163.0 13167.0 13180.0 13182.5 13185.5 13190.0 13192.5 13196.5 13199.0 13199.5 13203.5 13204.0 13207.5 13208.0 13210.5 13211.0 13214.0 13215.0 13217.0 13218.0 13227.5 13249.0 13113.5 13122.0 13125.5 13132.0 13133.0 13133.5 13144.0 13144.5 13145.0 13158.5 13166.0 13175.0 13175.5 13176.0 13177.0 13180.0 13183.5 13191.5 13193.0 13194.0 13196.5 13198.5 13200.5 13202.5 13208.5 13209.0 13227.0 13227.5 13261.5 13262.0 13268.5 13270.0 13271.0 13275.0 13306.0 13310.0 13316.5 13317.0 13318.0 13345.5 13354.5 13368.5 13384.0 13395.0 13402.0 13403.0 13404.0 13404.5 13406.0 13408.5 13412.0 13413.0 13426.0 13428.0 13428.5 13429.0 13430.0 13432.5 13437.0 13440.5 13443.5 13449.5 13454.5 13455.0 13456.0 13459.5 13460.0 13487.5 13488.5 13491.0 13492.0 13493.0 13494.5 13496.5 13497.0 13497.5 13498.0 13499.0 13524.0 13525.5 13531.5 13545.5 13546.5 13552.0 13560.5 13565.5 13572.5 13573.0 13260.5 13268.5 13270.0 13270.5 13274.5 13306.5 13310.5 13345.5 13354.0 13368.5 13383.5 13394.5 13402.0 13402.5 13404.0 13406.0 13408.0 13411.5 13412.0 13425.0 13427.5 13429.5 13433.0 13436.5 13443.5 13449.0 13454.5 13455.0 13455.5 13491.5 13494.5 13496.5 13497.0 13497.5 13498.0 13499.5 13532.0 13546.0 13546.5 13572.5 13573.5 13261.0 13317.5 13318.0 13318.5 13404.0 13428.0 13428.5 13440.0 13459.0 13460.0 13487.5 13488.0 13490.5 13493.0 13524.0 13525.0 13551.5 13559.5 13565.0 13575.0 13576.0 13577.0 13577.5 13582.5 13594.5 $ REMARKS.' 13575.5 13576.0 13583.0 13575.5 13576.0 13576.5 13595.0 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH3A. OUT / ? ?MATCH3 B. OUT $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 64 * DATA RECORD (TYPES 0) Total Data Records: 94 958 BYTES * Tape File Start Depth Tape File End Depth = 13620.000000 = 12965.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44576 datums Tape Subfile: 4 291 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass I gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: 1 1, 2, 3 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 SS PNAV 68 1 CPS 4 8 MSD PNAV 68 1 CU 4 9 RATO PNAV 68 1 4 10 RBOR PNAV 68 1 4 11 RICS PNAV 68 1 4 12 RIN PNAV 68 1 4 13. SGMA PNAV 68 1 CU 4 14 SGMB PNAV 68 I CU 4 15 SGNT PNAV 68 I CU 4 16 PHI PNAV 68 I PU-S 4 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 94 Tape File Start Depth = 13620.000000 Tape File End Depth = 12965.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44576 datums Tape Subfile: 5 116 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED BACKGROUND PASS Pulsed Neutron only: (neutron generator off). PASS NUMBER: 0 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH PDK $ Depth shifted and clipped curves for background pass .5000 START DEPTH 12977.0 12989.0 STOP DEPTH 13588.0 13600.0 BASELINE DEPTH GRCH 13021.5 13022.5 13022.5 13023.0 13025.5 13026.5 13043.0 13043.5 13053.5 13054.0 13054.5 13054.5 13062.5 13062.5 13079.0 13080.5 13089.0 13090.5 13090.0 13091.0 13090.5 13091.5 13095.5 13097.0 13104.0 13105.5 13105.0 13106.5 13106.0 13107.0 13110.5 13111.5 13119.0 13121.0 13124.0 13126.0 13125.0 13126.5 13127.5 13129.0 13136.0 13136.0 13137.0 13137.0 13138.0 13137.5 13140.5 13140.0 13148.5 13147.5 13159.0 13158.0 13163.5 13163.5 13166.0 13165.5 13168.0 13167.5 13169.5 13169.0 13176.0 13175.0 13180.5 13179.5 13183.0 13182.5 13187.0 13186.5 13187.5 13187.5 13190.0 13190.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 13194.0 13194.5 13196.5 13199.0 13204.5 13208.0 13217.0 13217.5 13228.0 13250.0 13261.0 13262.0 13267.0 13268.0 13268.5 13270.5 13271.0 13301.0 13302.5 13304.0 13311.5 13342.0 13413.5 13414.5 13430.5 13443.5 13448.0 .0 .5 .0 .5 .0 .0 13 13 13 13 13 13 13 13 13 13 $ 449 450 455 495 496 544 575.0 576.0 582.0 582.5 REMARKS: 13195.0 13195.5 13197.5 13200.0 13204.0 13207.0 13216.0 13217.0 13227.5 13249.0 13260.0 13260.5 13266.0 13267.0 13268.0 13270.0 13271.0 13300.5 13302.0 13304.5 13311.5 13341.5 13413.0 13413.5 13429.0 13443.5 13447.5 13448.0 13449.5 13454.5 13495.0 13496.0 13544.0 13575.0 13575.5 13581.5 13583.0 BACKGROUND PASS. BKL & BKS WERE SHIFTED WITH GRCH. / ? ?MATCH6. OUT $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units i GRCH PDK 68 i GAPI 2 BKL PDK 68 I CPS 3 BKS PDK 68 i CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 i 12 * DATA RECORD (TYPE# 0) Total Data Records: 21 1014 BYTES * Tape File Start Depth = 13620.000000 Tape File End Depth = 12965.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 6 49821 datums 128 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12988.0 PDK 13000.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13599.0 13611.0 22-DEC-94 FSYS REV. J001 VER. 1.1 1100 22-DEC-94 13678.0 13612.0 13000.0 13600.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL PDK PDK-100 SB SINKER BAR $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO'. CHOKE (DEG): .000 13760.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS) : 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): .0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 curVes: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GAPI 4 06 511 09 0 1 GR PDK 68 1 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19' SGMA PDK 68 1 CU 4 20 SGMB PDK 68 i CU 4 21 SGNT PDK 68 I CU 4 22 PHI PDK 68 i PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 00 201 24 4 71 162 89 6 4 05 626 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 52 386 28 5 4 17 922 28 5 96 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 257 Tape File Start Depth = 13615.000000 Tape File End Depth = 12974.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 108702 datums Tape Subfile: 7 332 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12987.0 PDK 12999.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13601.0 13613.0 22-DEC-94 FSYS REV. J001 VER. 1.1 1140 22-DEC-94 13678.0 13612.0 13000.0 13600.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL PDK PDK-100 SB SINKER BAR $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 13760.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS): 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): .0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 i CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 06 511 09 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 00 201 24 4 71 162 89 4 05 626 89 4 32 125 68 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 00 201 24 4 00 201 24 4 52 386 28 4 17 922 28 96 * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 257 Tape File Start Depth = 13617.000000 Tape File End Depth = 12976.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 113947 datums Tape Subfile: $ 332 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12986.0 PDK 12998.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13604.0 13616.0 22-DEC-94 FSYS REV. J001 VER. 1.1 1222 22-DEC-94 13678.0 13612.0 13000.0 13600.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL PDK PDK-100 SB SINKER BAR $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 13760.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 · BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 800 FAR COUNT RATE HIGH SCALE (CPS) : 3300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: PASS 3. $ .0 CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code SamPles units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 G1 PDK 68 1 CPS 9 G2 PDK 68 1 CPS 10 ISS PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SGNT PDK 68 1 CU 22 PHI PDK 68 1 PU-S 23 SPD PDK 68 1 F/MN 24 TEN PDK 68 1 LB 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 O0 201 24 1 4 4 71 162 89 6 4 4 05 626 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 52 386 28 5 4 4 17 922 28 5 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 260 Tape File Start Depth = 13619.000000 Tape File End Depth = 12971.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 173528 datums Tape Subfile: 9 335 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 0 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12976.5 PDK 12988.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP'LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): .LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 13605.0 13617.0 22-DEC-94 FSYS REV. J001 VER. 1.1 1012 22-DEC-94 13678.0 13612.0 13000.0 13600.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL PDK PDK-100 SB SINKER BAR $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 13760.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: BACKGROUND PASS, SOURCE OFF. $ CN : BP EXPLORATION WN : 3-41/K-39 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 CCL PDK 68 1 5 SPD PDK 68 1 F/MN 6 TEN PDK 68 1 LB 4 4 4 4 4 4 4 4 24 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 52 386 28 5 17 922 28 5 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 73 Tape File Start Depth = 13620.000000 Tape File End Depth = 12964.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 132323 datums Tape Subfile: 10 147 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 11 is type: LIS 94/12/28 01 **** REEL TRAILER **** 94/12/29 01 Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 29 DEC 94 9:10a Elapsed execution time = 21.47 seconds. SYSTEM RETURN CODE = 0 J d J d J d dj dj J d d ,.i J J JJ j j d J J J JJ JJ JJ JJ 0 0 0 0 0 ,o 0 0 0 0 0 0 0 0 0 O' 0 0 0 0 4 ,4 2 '! 0 2 0 · ¥ 4 S.;i_i i;'.'~ ? F::i C: k:: 2 5 0 ,~f" i: i,i L ~i!< 6 5 0" F E L TOOL STR~f-i~] RUN ~dZTH C!PEi,i HOLE PRESSURE ........................... 2: N8 STF:!NC:-iFF'.'--: ~i.",~ S:7'H r::f.~ N,'.q C:f2, L,-."CNS -~FTE~ t'-:~LT~"'-'~','r F:' ~q S S £:, U E 'i' 0 T .'-3 n L :.:.'; T P.".: Fi G E; L:i .T. 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'; '; ,::i';, ':.:,.c., 4 ,9 i 6 8 4 C~ i 6 8 ,:.i. 0 'i 6 8 4 0 i 6 8 4 fi i 6 8 ,:i. ~3 i 6 8 4 0 ! 6 8 4 0 i 6 8 4 0 i 6 8 4 ':",.., i 6 8 '~ 6 0, '?9 !} 0, 0 0 0 'i 0 0 0 t::', 0, 0 2 ;'} 0, 0 0 0 ~'" i 2 i , 0:3 6 2:~:, 5 '.;. r S 2, :3 ::.:-: 5 4 7,4 2 4 File t,.....:pe~ LO 'S~:r-vi:z:!~: name: %:GSF:01 fi:, a t. e: 8 ;32 0 ! ,-" 04. Or'igin: S 92 2 8 8 0 r- i g i ;",.: 1,~92288