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Home My WebLink About203-016New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-38A Open hole patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-016 50-029-22496-01-00 14142 Surface Production Liner Liner Liner 8941 3530 9420 2309 1080 4182 14109 13-3/8" 9-5/8" 7" 4-1/2" 4-1/2" x 3-3/16" x 2-7/8" 8939 35 - 3530 30 - 9420 9277 - 11586 11447 - 12527 9960 - 14142 35 - 3530 30 - 8312 8222 - 8918 8924 - 8915 8639 - 8941 none 2270 4760 7820 7500 11160 none 5020 6870 9690 8430 10570 11330 - 14090 4-1/2" 12.6# L-80 28 - 9997 8924 - 8938 Structural 4-1/2" Baker SABL-3 , 9935 , 8624 No SSSV 9935 8624 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 , 0028306 28 - 8660 355 785 41533 9709 36 56 0 0 1221 1138 322-319 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Meredith Guhl at 12:37 pm, Feb 17, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.17 11:28:59 -09'00' DSR-2/22/23 Sundry Number Repair Well 322-319 WCB 11-20-2023 RBDMS JSB 022123 PBU 15-38A Open hole patch PRUDHOE BAY, PRUDHOE OIL 203-016 ACTIVITYDATE SUMMARY 11/28/2022 ***Start Job** CTU #9 1.75" Coil 0.145 Wall Job Scope: Log/Drift, Caliper, & 3-1/2" Patch MIRU CTU #9 ***Job in Progress*** 11/29/2022 ***Continue on from WSR 11/28/22*** CTU #9 1.75" Coil 0.145 Wall Job Scope: Log/Drift, Caliper, & 3-1/2" Patch MU NS ctc & MHA. MU GR/CCL w/ 2.73" DJN. WHP 2375 psi - Kill well, log from 12634 to 9700. POOH, tie in w/+26ft correction. RIH with caliper, log from 12700- 9800. POOH. Verify data. ***Continue on to WSR 11/30/22*** 11/30/2022 ***Continue on from WSR 11/29/22*** CTU #9 1.75" Coil 0.145 Wall Job Scope: Log/Drift, Caliper, & 3/1-2" Patches Wait on Caliper Data. OE approved perfs depths. Deploy 1st Patch and RIH. Correct Depth at Flag. Set NS 272-350 Patch @ 11,625'-11,660'. POOH. Undeploy setting tool. Deploy 2nd Patch and RIH. Correct Depth at Flag. Set NS 272-350 Patch @ 11,325'-11,360'. Min ID =1.81". POOH. Lay down patch setting tool. Freeze protect to 2500' TVD with diesel. RDMOL. ***Drawings of NS Patches are in Well Picture folder*** ***Job Complete*** 12/26/2022 ***POLLARD UNIT #59 WEATHER HOLD*** 12/27/2022 T/I/O= NA TEMP= SI (PATCH TUBING / LINER) Assist Sline as directed. Spot up standby for weather ***Job cont. to 12-28-22 WSR*** 12/27/2022 ***CONTINUE FROM 12/26/22*** POLLARD UNIT #59 ON WEATHER HOLD ***CONTINUE ON 12/28/22*** 12/28/2022 ***Job cont. from 12-27-22 WSR*** T/I/O= 1900/350/225 TEMP=SI Pumped 225 bbls of 60* crude down Tbg for load and B&F. Pumped 5 bbls crude to pressure up on plug unable to reach test pressure obtained LLR of .3 @ 2700 psi . Pumped 2 bbls 60* crude down Tbg to bring psi up to 2500 psi monitor psi . 1st 15min Tbg lost 100 psi // 2nd 15min= Tbg lost 25 psi ***Job cont to 12-29-22*** 12/28/2022 ***CONTINUE FROM 12/27/22 POLLARD UNIT #59 ON WEATHER HOLD BRUSHED 4 1/2" TUBING & DEPLOYMENT SLEEVE WHILE THUNDERBIRD LOAD TUBING W/ 225 BBLS OF CRUDE RAN 45 KB UPPER & PTSA DRIFT TO DEPLOYMENT SLEEVE @ 9,968' MD SET 45KB PACKER w/ NORTHERN SOLUTIONS PTSA w/ 2.31" XX PLUG INSTALLED. ATTEMPT TO MITT 2500 PSI. UNABLE TO PREEURE TBG. PUMPING .3 BBLS/MIN @ 2700 PSI. SET 45KB TEST TOOL IN PACKER @ 9935' SLM. MITT 2500 PSI AGAINST TEST TOOL (PASS). ***WSR CONTINUED ON 12-29-22*** 12/29/2022 ***Job cont from 12-28-22 WSR*** Pumped 10 bbls of 25* crude down Tbg while Sline runs in hole. Pumped 4 bbls crude down Tbg achieve LLR of .3 bpm @2625 psi FWHP=500/350/225 SLine in control of well upon departure Daily Report of Well Operations PBU 15-38A CTU #9 1.75" Coil 0.145 Wall Job Scope: Log/Drift, Caliper, & 3-1/2" Patch g MU NS ctc & MHA. MU GR/CCL w/ 2.73" DJN. y Set NS 272-350 Patch @ 11,625'-11,660'. POOH Set NS 272-350gy Patch @ 11,325'-11,360'. Patches are shown correctly on the WBS, below. -WCB Caliper pulled to "see" perfs. -WCB Kill well, log fromg 12634 to 9700. POOH, tie in w/+26ft correction. RIH with caliper, log from 12700- 9800. POOH. Verify data RAN 45 KB UPPER & PTSA DRIFT TO DEPLOYMENT SLEEVE @ 9,968' MD@ SET 45KB PACKER w/ NORTHERN SOLUTIONS PTSA w/ 2.31" XX PLUG INSTALLED. Daily Report of Well Operations PBU 15-38A 12/29/2022 ***WSR CONTINUED FROM 12-28-22*** PULLED 45KB TEST TOOL FROM 9931' SLM. PULLED 2.31" XX PLUG FROM 9944' SLM (LOOKS GOOD). ***MISSING DOWEL FROM 2 7/8" GU ADAPTER. SET X SELECTIVE TEST TOOL @ 9946' SLM. ATTEMPT TO PT TBG; LEAK RATE OF .3 BBLS/MIN @ 2625 PSI. PULLED 45KB LTP FROM DEP SLEEVE ***UPPER SET OF LOWER SEALS TORE UP, MISSING ONE LTP ELEMENT RAN 4-1/2" BRUSH w/ 3.61" x 3 PRONG WIRE GRAP TO DEP SLEEVE **RECOVERED 4" x 1/2" PIECE OF ELEMENT **JOB INCOMPLETE, WILL RETURN WITH NEW PACKER CONFIGURATION** 1/4/2023 (PATCH TUBING / LINER) Assist Sline as directed. Spot up Standby for SLine 1/5/2023 ***Job cont from 01-04-23 WSR*** (PATCH TUBING / LINER) Called off Job due to SLine Stuck in hole on D pad. Sline in control of well upon departure. DSO notified of well status. 1/5/2023 ***WELL S/I ON ARRIVAL*** STBY FOR WINDS TRAVEL TO SHOP DUE TO DRIFTING ON PAD ***CONTINUE 1/6/23*** 1/6/2023 ***Standby for Weather*** TFS U-3 1/7/2023 ***Weather Standby*** TFS U-3 1/9/2023 ***WELL S/I ON ARRIVAL*** (Patch tubing / liner) TAG DEPLOYMENT SLEEVE AT 9,933' SLM W/ 3.79" SWAGE (Good ring from fish neck). DRIFT TO 9,933' SLM W/ DUMMY NS SNAP LATCH RECEPTACLE, SPACER, 35KB ANCHOR PACKER. HAD TO WORK DUMMY PACKER TO NO-GO BUT AFTER WENT IN / OUT WITH LITTLE EFFORT. ATTEMPT TO SET 3-1/2" XN x 1.781" R-NIPPLE REDUCER AT 9,987' MD (Spongy possible element). BRUSH DEPLOYMENT SLEEVE & 2.75" XN NIPPLE W/ 3-1/2" BRUSH, G-RING. AFTER PASSING THROUGH XN NIPPLE APPEARED TO PUSH SOMETHING DOWNHOLE TO ~10,050' SLM. SET 3 1/2" XN x 1.781" R-NIPPLE REDUCER AT 9,987' MD. RAN 3 1/2" CHECK SET TO NIPPLE REDUCER AT 9,987' MD(Sheared). DRIFTED 9,952' SLM w/ DUMMY SNAP LATCH RECEPTACLE, SPACER, 35KB ANCHOR PACKER(Drifted freely into deployment sleeve) ***CONTINUED ON 1/10/23 WSR*** 1/10/2023 ***CONTINUED FROM 1/9/23 WSR*** (Patch tubing liner) DRIFT TO 9,935' SLM w/ 45KB PACKER DRIFT,2 7/8" SPACER PIPE,45KB LOWER PACKER DRIFT. ***WELL S/I ON DEPARTURE*** 1/24/2023 Travel to location, Stby for S-Line. No fluids pumped RAN 3 1/2" CHECK SET TO NIPPLE REDUCER AT 9,987' MD(Sheared). SET 3 1/2" XN x 1.781" R-NIPPLE REDUCER AT 9,987' MD Daily Report of Well Operations PBU 15-38A 1/24/2023 ***WELL S/I ON ARRIVAL*** PULLED NIPPLE REDUCER FROM 9987' MD (ensure expander mandrel is tapered) RE-SET 3 1/2" XN x 1.781" R NIPPLE REDUCER @ 9987' MD. RAN CHECK SET TO CONFIRM GOOD SET. SET LOWER 20.46' x 35KB STRADDLE LTP ASSY @ 9968' SLM. SET UPPER 19.42' x 45KB STRADDLE LTP ASSY IN LOWER ASSY @ 9948' SLM. ***WSR CONTINUED ON 1-25-23*** 1/25/2023 ***WSR CONTINUED FROM 1-24-23*** SET 1.781" RX PLUG @ 9987' MD. UNABLE TO PRESSURE TBG. PULL & RE-SET PLUG MULTIPLE TIMES, AND STILL UNABLE TO GET PT ON TBG (LLR of 2.9 bbls/min @ 1000 psi; 4.1 bbls/min @ 1500 psi). SET 45KB TEST TOOL @ 9924' SLM; PT TBG 1500 PSI (45KB PACKER HOLDING). PULLED 1.781" RX PLUG FROM 9987' MD. ***WELL S/I ON DEPARTURE*** 1/25/2023 ** Assist Slickline** T/I/O=2500/330/240 Pumped 244 bbls crude to load TBG. Unable to pressure up on plug. LLR=2.9 BPM @ 1000, 4.1 BPM @ 1400 Called off job. FWHP=320/320/240. S-Line on location upon departure SET LOWER 20.46' x 35KB STRADDLE LTP ASSY @ 9968' SLM.@ SET UPPER 19.42' x 45KB STRADDLE LTP ASSY IN LOWER ASSY @ 9948' SLM SET 1.781" RX PLUG @ 9987' MD. UNABLE TO PRESSURE TBG RAN CHECK SET TO CONFIRM GOOD SET. ( RE-SET 3 1/2" XN x 1.781" R NIPPLE REDUCER @ 9987' MD. 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ŽŶƚĂĐƚKƚŽǀĞƌŝĨǇƚŝĞŝŶǁͬĂĚĚŝƚŝŽŶĂůĐĂůŝƉĞƌĚĂƚĂĨƌŽŵƐƚĞƉϯ͘ůĞŵĞŶƚƐĞƚĚĞƉƚŚƐŵĂǇďĞ ĂĚũƵƐƚĞĚďĂƐĞĚŽŶĐĂůŝƉĞƌĚĂƚĂ͘ ϭϬ͘ Z/,ĂŶĚƐĞƚŽŶĞƚƌŝƉϯϱ͛ƚŽƉĂƚĐŚΛϭϭϲϲϬ͛ďŽƚƚŽŵĞůĞŵĞŶƚĂŶĚϭϭϲϮϱ͛ƚŽƉĞůĞŵĞŶƚ͘ ϭϭ͘ ĨƚĞƌůĂŶĚŝŶŐƉĂƚĐŚ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞƐĞƚƚŝŶŐ ĂƐƐĞŵďůǇĂŶĚƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ ϭϮ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϯ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨƐĞƚƚŝŶŐƌŽĚ,͘ ϭϰ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ƐĞƚƚŝŶŐƌŽĚ ,͘ ϭϱ͘ >ĂǇĚŽǁŶƐĞƚƚŝŶŐƌŽĚ,͘ ϭϲ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨĞǆƚĞŶĚĞĚĂƐƐĞŵďůǇηϮ͘ ϭϳ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϰƉƉŐϭй<ůŽƌϴ͘ϱ ƉƉŐĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵď ƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲĞƐƚĂďůŝƐŚĞĚ͘ &ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĂƚĐŚĂƐƐĞŵďůǇƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐ ŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϴ͘Ύ/ĨŶĞǁĐƌĞǁŝƐŽŶƚŽƵƌĨƌŽŵƐƚĞƉϳƚŚĞŶƉĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚ ƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶ ĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶƐƚƌŝŶŐ͘KŶĐĞƚŚĞƐĂĨĞƚǇũŽŝŶƚ ĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨ ŶĞĐĞƐƐĂƌǇ͘ Ă͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƚŽƉ ƚŚƌĞĂĚƐŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘ ϭϵ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨƉĂƚĐŚĂƐ ƐĞŵďůǇƉĞƌƐĐŚĞŵĂƚŝĐ͘ŽŶƐƚĂŶƚůǇ ŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚ ǁŚŝůĞĚĞƉůŽǇŝŶŐƉĂƚĐŚĂƐƐĞŵďůǇƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϮϬ͘ DhϯϭͬϮ͟ƉĂƚĐŚƉĞƌƐĐŚĞŵĂƚŝĐĂŶĚŶŽƌƚŚĞƌŶƐŽůƵƚŝŽŶƐ͘dŚĞƉĂƚĐŚĂŶĚƐĞƚƚŝŶŐƐůĞĞǀĞǁŝůůďĞƉŝĐŬĞĚƵƉ ĂŶĚĚĞƉůŽǇĞĚŽƉĞŶŚŽůĞŝŶŽŶĞƉŝĐŬǁŝƚŚĂůŝĨƚŝŶŐƐƵď͘ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ Ă͘ ŽŶƚĂĐƚKƚŽǀĞƌŝĨǇƚŝĞŝŶǁͬĂĚĚŝƚŝŽŶĂůĐĂůŝƉĞƌĚĂƚĂĨƌŽŵƐƚĞƉϯ͘ůĞŵĞŶƚƐĞƚĚĞƉƚŚƐŵĂǇďĞ ĂĚũƵƐƚĞĚďĂƐĞĚŽŶĐĂůŝƉĞƌĚĂƚĂ͘ Ϯϭ͘ Z/,ĂŶĚƐĞƚŽŶĞƚƌŝƉϯϱ͛ƚŽƉĂƚĐŚΛϭϭϯϲϬ͛ďŽƚƚŽŵĞůĞŵĞŶƚĂŶĚϭϭϯϮϱ͛ƚŽƉĞůĞŵĞŶƚ͘ ϮϮ͘ ĨƚĞƌůĂŶĚŝŶŐƉĂƚĐŚ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶ͛ƚĨĂůůŝŶŽŶƚŚĞƐĞƚƚŝŶŐ ĂƐƐĞŵďůǇĂŶĚƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌǇďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ Ϯϯ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ Ϯϰ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ^ƚĂŶĚŝŶŐKƌĚĞƌƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘ Ϯϱ͘ ŶƐƵƌĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůǇĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ƐĞƚƚŝŶŐƌŽĚ ,͘ Ϯϲ͘ ZDKdh͘ Ϯϳ͘ ZdWŽƌ&WǁĞůů͘ ^ůŝĐŬůŝŶĞͬ&ƵůůďŽƌĞ ϭ͘ ůŽĂĚƚƵďŝŶŐǁͬĐƌƵĚĞ;ϮϮϱďďůƐͿƉĞƌt^>ƉƌŝŽƌƚŽƐĞƚƚŝŶŐ>dW͘ Ϯ͘ ^ĞƚŶĞǁϰЪ͟<ůŝŶĞƌƚŽƉƉĂĐŬĞƌǁͬWd^͘sĞƌŝĨǇƐƉĂĐĞƌƉŝƉĞůĞŶŐƚŚǁŝƚŚKƉƌŝŽƌƚŽƌŝŐƵƉ͘tĞǁŝůů ƌĞǀŝĞǁƚŚĞĐĂůŝƉĞƌĚĂƚĂĨŽƌĂƉƉƌŽƉƌŝĂƚĞƐƉĂĐĞŽƵƚ͘ ϯ͘ D/dͲdƚŽϮϱϬϬƉƐŝ ϰ͘ ^ĞƚŬŝĐŬŽĨĨ'>sĚĞƐŝŐŶƚŽĂƐƐŝƐƚǁŝƚŚƉŽƉƉŝŶŐǁĞůůƉŽƐƚĐŽŝů ͘ ϱ͘ WƵůůƉůƵŐĨƌŽŵƚŚĞWd^ KƉĞƌĂƚŝŽŶƐ ϭ͘ WůĂŶƚŽƉŽƉǁĞůůƚŽ,W͕ƵƐĞW'>ŝĨŶĞĐĞƐƐĂƌǇĂƐ^>ƐĞƚ<KĚĞƐŝŐŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϱ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ ϲ͘ WĂƚĐŚ^ĐŚĞŵĂƚŝĐ ϳ͘ DŝŶŝůŽŐ ϴ͘ ϭϬͲϰϬϯŚĂŶŐĞ&Žƌŵ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ ŽŝůĞĚdƵďŝŶŐKWƐ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ WĂƚĐŚ^ĐŚĞŵĂƚŝĐ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ 0LQLORJ KƉĞŶ,ŽůĞWĂƚĐŚ tĞůů͗ϭϱͲϯϴ Wd͗ϮϬϯϬϭϲ &KDQJH)RUP 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 15-38A Coil patch over liner perfs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-016 50-029-22496-01-00 ADL 0028309 14142 Surface Production Liner Liner Liner 8941 3530 9420 2309 1080 4182 14109 13-3/8" 9-5/8" 7" 4-1/2" / 8939 35 - 3530 30 - 9420 9277 - 11586 11447 - 12527 9960 - 14142 35 - 3530 30 - 8312 8222 - 8918 8924 - 8915 8639 - 8941 none 2270 4760 7820 7500 11160 none 5020 6870 9690 8430 10570 11330 - 14090 4-1/2" 12.6#L-80 28 - 99978924 - 8938 Structural 4-1/2" Baker 9935 8624 Date: Bo York Operations Manager Ryan Thompson Ryan.Thompson@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 4-1/2" x 3-3/16" x 2-7/8" 10/01/2021 No SSSV (TRDP4A locked out)2228 2228 By Samantha Carlisle at 2:38 pm, Sep 07, 2021 321-452 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.07 14:08:25 -08'00' Bo York 10-404 ; ADL0028306 DLB X MGR15SEP2021 DSR-9/7/21DLB 09/07/2021 dts 9/15/2021 JLC 9/15/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.16 10:10:15 -08'00' RBDMS HEW 9/16/2021 Open Hole Patch 15-38A PTD: 203016 Well Name:15-38A API Number:500292249601 Current Status:Shut In Rig:CTU & SL Estimated Start Date:October 2021 Estimated Duration:2 days Regulatory Contact:Carrie Janowski Permit to Drill Number:203016 First Call Engineer:Ryan Thompson (907) 301-1240 Second Call Engineer:Torin Roschinger (406) 570-9630 (c) AFE Number:215-01853.16.11 IOR 100 Current Bottom Hole Pressure:3144 psi @ 8,800’ TVD 6.9 PPG (offset well 15-42B) Current Bottom Hole Temperature:170° deg F Maximum Expected BHP:3382 psi @ 8,800’ TVD 7.4 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2502psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2350 psi (Taken on 6/29/2021) Min ID:2.372” ID – 12675’ MD Max Angle:96 Deg @ 13260’ Reference Log:SLB – MCNL – 12/11/04 Brief Well Summary: 15-38A was drilled as a CTD sidetrack in 2003 and has been a cycle well since 2013. In 2008 the upper liner was perfed to access the 15-38 motherbore. The well was SI for HGOR in February 2020. Objective: The objective of this procedure is to run two patches with open hole deployment and set them in the 3 3/16” liner to isolate 2 sets of perforations shutting off production from the 15-38 motherbore. A LTP will be set in the well after the patches are set. Program Slickline – Complete 7/15/21 1. Pull LTP from 9968’ MD. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before deploying the patches. Coiled Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Drift to XO @ 12675’ w/ ~2.72” nozzle w/ GR/CCL. Flag for tie in. 3. Run 24 arm caliper (1.69” OD), from 12675’ to ~9800’ MD. Rush process the caliper data to verify perf intervals for patch tie in. 4. Bullhead 245 bbls of KWF, 8.4 ppg 1% KCl, seawater or equivalent down the tubing to the formation. a. Wellbore volume to top perf = 163 bbls b. 15-38A was load and killed on 7/15/21. We were able to pump 5 bbls/min for the duration so presumably we do not have a tight formation. 5. Perform no flow check prior to breaking lubricator at QTS connection. x Review well control steps with crew prior to breaking lubricator connection and commencing picking up the patch open hole. Once the safety joint and TIW valve have been spaced out, keep the -00 DLB Open Hole Patch 15-38A PTD: 203016 safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. Verify XO from safety joint to patch lifting sub is correct. Note this assembly can be pulled above the BOP rams in a single pick. 6. MU 3 1/2” patch per schematic and northern solutions. The patch and setting sleeve will be picked up and deployed open hole in one pick with a lifting sub. a. Contact OE to verify tie in w/ additional caliper data from step 3. Element set depths may be adjusted based on caliper data. 7. RIH and set one trip 35’ E to E patch @ 11660’ bottom element and 11625’ top element. 8. POOH and perform flow check prior to laying down the patch setting rod open hole. 9. MU 3 1/2” patch per schematic and northern solutions. The patch and setting sleeve will be picked up and deployed open hole in one pick with a lifting sub. a. Contact OE to verify tie in w/ additional caliper data from step 3. Element set depths may be adjusted based on caliper data. 10. RIH and set one trip 35’ E to E patch @ 11360’ bottom element and 11325’ top element. 11. POOH and perform flow check prior to laying down the patch setting rod open hole. 12. RDMO End of 10-403 Approval Sundry Procedure Slickline/Fullbore 1. Obtain fluid level shot, if necessary load tubing w/ crude (225 bbls) per WSL prior to setting LTP if FL warrants. 2. Set new 4 ½” KB liner top packer w/ PTSA. Verify spacer pipe length with OE prior to rig up. We will review the caliper data for appropriate space out. 3. MIT-T to 2500 psi 4. Set kick off GLV design to assist with popping well post coil. 5. Pull plug from the PTSA Operations 1. Plan to pop well to HP, use DPBGL if necessary as SL set KO design. MU PCE. MU PCE. Open Hole Patch 15-38A PTD: 203016 Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Patch Schematic 4. BOPs 5. Standing Orders 6. Liner Tally 7. Tie in log Open Hole Patch 15-38A PTD: 203016 Current Wellbore Schematic Open Hole Patch 15-38A PTD: 203016 Proposed Schematic Open Hole Patch 15-38A PTD: 203016 Patch Schematic Open Hole Patch 15-38A PTD: 203016 BOPs Open Hole Patch 15-38A PTD: 203016 Standing Orders Open Hole Patch 15-38A PTD: 203016 Equipment Layout Diagram Open Hole Patch 15-38A PTD: 203016 Liner Tally Open Hole Patch 15-38A PTD: 203016 Tie In Log Open Hole Patch 15-38A PTD: 203016 Open Hole Patch 15-38A PTD: 203016 Comments about this file Quality Checked I I 11111 I 151 III BY: Helen Maria Date: ReScanned I I 111111 1 II Scanning is complete at this point unless rescanning is required. BY: Stage 1 BY: Page Count Hele~Maria If NO in stage Helen Maria 1 Matches Number ) Date: I I II 151 1III1 I page( s) discrepancies were found include cover sheet) VYES Date: 4 7/ os YES NO NO Isl 1tV1 P I . in Scanning Preparation Stage 1 Page Count from Scanned File: ~o (Count does Production Scanning BY: Scanning Preparation Hele{c-¡- Maria) ----- ~ x 30 = ftJD + C¡ = TOTAL PAGES I (Count doe!; n,ofinCIUde cover Date: lJ-> 7/ ns- Is/ . 111111111I I °9 sheet) 'mP II 117/~- mf BY: Helen C. Maria) Date: 151 Project Proofing BY: Helere Mari~ o Other: Date: 1f-/7/óS 1111111 151 II I II II JlMP NOTES: o Logs of various kinds: R~AN ¢' Color Items o Greyscale Items: o Other: o Poor Quality Originals: DIGITAL DATA ~skettes, No. g.. o Other, No/Type: OVERSIZED (Non-Scannable) o Maps o Other Items Scannable by a Large Scanner Organizing (done) o Two-sided I I III II 1111 ~scan Needed OVERSIZED (Scannable) I ! I I 'I I III This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 30ð - DJ 0 Well History File Identifier XHVZE mage Project ') Well History File Cover Page ) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 3 - O/ January 6, 2012 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission E Mkt ;; 20 12 333 West 7 Avenue Anchorage, Alaska 99501 u:: `- = 's, a s O TiiS51Oi Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 907 - 659 -5102. Sincerely, StAP4NED FEB 2 , 7 2012 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-15 Date: 11/09111 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft 9a 15- 018 2042570 50029206960200 15-028 2060720 50029206970200 15-03 1820300 50029207220000 15-048 2071380 50029207260200 15-05A 1950340 50029207310100 15-06A 1982540 50029207420100 15-07C 2030970 50029211660300 15-08C 2050050 50029211800300 15-09A 1931380 50029212010100 15-10A 1880850 50029205010100 15- 118 2041460 50029206530200 15- 128 2060870 50029206650200 15-13A 1991240 50029206450100 15-14A 2042220 50029206820100 15-15C 2081820 50029206910300 15- 168 2011920 50029211150100 15-17 1840890 50029211260000 15-18A 2080830 50029222740100 0.4 NA 0.4 NA 5.1 11/9/2011 Additional treatment 15-19A 1990990 50029218290100 Dust Cover NA NA NA 10.2 11/912011 15-20C 2050930 50029211330300 15-21A 1990290 50029205030100 15-22 1800970 50029205090000 15-23A 2031110 50029222250100 15-24 1911280 50029222230000 15-25B 2080240 50029218420200 15-26B 2041590 50029222350200 15-27 1920060 50029222430000 15-28A 2031240 50029222470100 15- 298 2090380 50029222590200 0.1 NA 0.1 NA 3.4 11/9/2011 Additional treatment 15-30A 2020890 50029222820100 15-31B 2050860 50029222850200 15-32A 2011840 50029224620100 15-338 2031940 50029224480200 15-34A 2001370 50029224740100 15-35 1940880 50029224880000 15-36B 2060730 50029224800200 15-37B 2040190 50029224850200 ----P 15-38A 2030160 _ 50029224960100 Dust Cover NA NA NA 3.4 11/5/2011 15-39A 2060860 50029225030100 0.3 NA 0.3 NA 3.4 11/5/2011 Additional treatment 15-40A 1980980 50029225110100 15-41B 2011460 50029224920200 15-426 2090730 50029226240200 15-43 1960830 50029226760000 4 NA 4 NA 30.6 11/9/2011 15-44 1961100 50029226830000 15-45B 2071790 50029226710200 15-46 2041030 50029226650000 15-47 1951740 50029226170000 15-48B 2051660 50029226350200 15-498 2090640 50029226510200 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 • January 1, 2010 ~a' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission b~... 333 West 7t" Avenue Anchorage, Alaska 99501 ~ ~-- ~~~" Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 naro• nvnswn Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-018 2042570. 50029206960200- NA Sealed NA 15-02B 2060720. 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10!2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-118 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7!2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-266 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-418 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 ~~ 9 0~ ~~~11~ . STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMON ~~~ 2 ~ ZOO$ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~S ~Uf1S. CQm Performed: Aiter Casing ~ Pull Tubing ~ Perforate New Pooi ~ Waiver ~ Time Extension ~ Af1C~CJCa~e Change Approved Program ~ Operat. Shutdown ~ Perforate ~- Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' ~ Exploratory 203-0160 , 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22496-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 66.05 KB i PBU 15-38A - 8. Property Designation: 10. Field/Pool(s): ADLO-028309 ~ PR.U9HOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 14142 - feet Plugs (measured) None true vertical 8941 - feet Junk (measured) None ~` L, s Effective Depth measured 14109 - feet ~~V~~~6~~ ~~~ ~ ~ 200 "~ true vertical 8939.03 feet ~'` ~! Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 30' - 110' 30' - 110' 1490 470 Surface 3530' 13-3/8" 68# NT80CYHE 35' - 3530' 35' - 3530' 5020 2270 Production 9420' 9-5/8" 47# NT80S 30' - 9420' 30' - 8312' 6870 4760 Liner 2309' 7" 29# NT95HS 9277' - 11586' 8222' - 8918' 9690 7820 Liner 1080' 4-1/2" 12.6# L-80 11447' - 12527' 8924' - 8915' 8430 7500 Liner 4182' 4.5 8.81 6.2 6.16# 9960' - 14142' 8639' - 8941' Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9997' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BAKER SABL-3 9935' 4-1/2" BKR RETRIEVABLE 11440' 4-1/2" TIW SS HORIZ PKR 11447' 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 494 23692 7 436 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~- - Service Daily Report of Well Operations X 16. Well Status after proposed work: 0iI ' ~ Gas WAG .(~' GINJ WINJ ~ WDSPL 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 Gary Preble Printed Name Gary Pr e Title Data Management Engineer Signature Phone 564-4944 Date 8/28/2008 ii aSiO l ~ ~~'"~_ SEP ~ ~ 100 1 ", Form 10-404 Revised 04/20 Submit Original Only 4 15-38A 203-0160 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-38A 2/10/03 PER 12,740. 13,030. 8,932.8 8,940.97 15-38A 2/10/03 PER 13,250. 13,560. 8,942.03 8,935.31 15-38A 2/10/03 PER 13,690. 13,800. 8,933.57 8,928.85 15-38A 2/10/03 PER 13,850. 13,870. 8,928.46 8,928.88 15-38A 2/10/03 PER 13,890. 13,930. 8,929.45 8,930.74 15-38A 2/10/03 PER 14,020. 14,090. 8,935.22 8,938.25 15-38A 8/21/08 PER 11,330. 11,355. 8,923.57 8,924.62 15-38A 8/21/08 PER 11,630. 11,655. 8,915.95 8,915.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 15-38A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY "'""'"""~ "`SWELL SHUT IN ON ARRIVAL"" INITIAL T/I/O = 200/ 600/ 350 PSI. `RIG UP E-LINE UNIT FOR PERFORATING USING WELLTEC TRACTOR. ***CONTINUE JOB ON 21-AUGUST-2008 WSR**" 3 ~*'`CONTINUE FROM 8/20/08 WSR'`'`* PERFORATE FROM 11330' - 11355' & 11630' - 11655' USING WELLTEC NO ISSUES RUNNING IN OR PULLING OOH. TIE IN LOG SLB MCNL 12/11/2004, REFERENCE LOG SLB GR/CCL 2/10/2003. FINAL T/I/O = 250/600/350 VALVE STATUS: MASTER OPEN, SSV CLOSED, SWAB CLOSED. CASING VLV'S OPEN TO GAUGES. PAD-OP CONFIRMED PRIOR TO LEAVING. "**JOB COMPLETE`** FLUIDS PUMPED BBLS 1 diesel 1 Total • _.,, ~ , 6s sb9`" MtCROFtLMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_InsertslMicrofilm_Marker. doc 07/23/07 Schlumberger NO. 4339 %: ;) Z007 {)o3 --0 l (0 Company: SCANNED JUL 2 7 Z007 r..ommì$sior¡ tt (~d(f7 State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Oil 8, Field: Prudhoe Bay WI! J b# CD L D D t BL CI e 0 og eSCrlptlon ae o or 5-400 40012946 OHI:UlI 2 1 W-01A 40012483 OH I:UII 11/06/05 2 1 S-401 (REVISED) 40014121 OH EDIT MWD/LWD 10/21/06 2 1 S-401 PB1'(REVISED) 40014121 OH EDIT MWD/LWD 10/08/06 2 1 C-17B 10715418 MCNL 08/10/04 1 L5,15 11626485 RST 05/12/07 1 1 N-15 11637129 RST 01/13/07 1 1 15-38A 10715446 MCNL 12/11/04 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: Received by: 1\ . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 12-14 Ll Ll PBl, 14-17A, 14-30A, 15-38A_PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 l2-14A Ll Ll PBI: god- -tdd # I~¿IS-I Digital Log Images: 50-029-20659-60, 71 I CD Rom 14-17 A: U Ie... c9ó3 -DO ·1'ft./~'ð Digital Log Images: 50-029-20562-01 l4-30A: d oS- -0 q~( ~ I'-I¿/~O Digital Log Images: 50-029-20679-01 1 CD Rom 1 CD Rom 15-38A_PBl: ~03-0/0 tt. fL/L/LIC¡ Digital Log Images: 50-029-20679-01 I CD Rom scANNED FEB 0 1 2007 -- e 1~?54--- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 1 February 23, 2004 RE: MWD FonnationEvaluationLogs 15-38A& 15-38APB1, AK.-MW-30020 15-38A+PBl: Digital Log Images: 50-029-22496-01, 70 )D/J~ O(G 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ Date#- r- Sign~Íill0 f) Permit to Drill 2030160 MD 14142 i' MM M-o ð- DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 )f7¿;'~ J {J<.V\. ÀÚ~J API No. 50-029-22496-01-00 Well Name/No. PRUDHOE BAY UNIT 15-38A Operator BP EXPLORATION (ALASKA) INC TVD 8937 Completion Date 2/11/2003 UIC N Completion Status 1-01l Current Status 1-01l REQUIRED INFORMATION Samples No -- --- --~-- Mud log No Directional survey",-~ DATA INFORMATION Types Electric or Other Logs Run: DGR, MGR, CCl Well Log Information: (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset :?;__ ~e~!nnt ~~~r -o__~~ Cßl' D ~D Rpt Rpt ~D ~ D log Rpt I 6.ED C , Rpt Rpt bE'6 D Name Casing collar locator ("1)irectional Survey ß-ectional Survey Log Log Scale Media Interval Start Stop 9764 14094 12731 14142 12463 13369 Received Comments 5/13/2003 3/26/2003 3/26/2003 PB1 Run No 1 ~ OH/ CH Open Open Open Directional Survey Directional Survey 11639 b.13 Vcrifi€i~ C:> r1.. ¥to çtJ An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. 12463 13369 Open 3/26/2003 PB1 12731 14142 Open 3/26/2003 11240 14114 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/28/2003. PB1 4 V1'1640 blS Vorifioation G "- Gamma Ray LIS Verification {Jv:Ji' 11240 13341 Open 4/29/2003 9764 14094 Open 5/13/2003 11240 14114 Open 7/24/2003 REPLACES DATA RCVD 04/29/2003 25 Blu 4 c;1A722 Gamma Ray LIS Verification 9764 14094 Open 5/13/2003 11240 14114 Open 4/29/2003 REPLACED BY NEW DATA RCVD 07/24/2003 PB1 REPLACED BY NEW DATA RCVD 07/24/2003 LIS Verification 11639 HS VQrificat}rm \ fZ f'\..of1 11240 13341 Open 4/29/2003 11240 14114 Open 4/29/2003 DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2030160 Well Name/No. PRUDHOE BAY UNIT 15-38A Name Interval Start Stop Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22496-01-00 Completion Status 1-01L Current Status 1-01L UIC N 25 Blu 9764 14094 Open 5/13/2003 11245 14114 1 0/1 0/2003 11245 14114 10/10/2003 11245 14114 10/10/2003 11245 14114 10/10/2003 11245 13343 1 0/1 0/2003 PB1 11245 13343 1 0/10/2003 PB1 ~ Sample Set Sent Received Number Comments MD 14142 TVD 8937 Completion Date 2/11/2003 --- -------~- Log Casing collar locator ED D Tf .~US-VorificatiOrt Gr\ y\ ú y.1 I { ~:> ,t Rpt LIS Verification ED D ~ Rate of Penetration Rpt Rate of r'cnetralion /'LGJ# ED D Tf .~ R~to of rcllt:hatlon ~ y2.. I Rpt {{ CD ..( Ò R;:¡te of Penetr;:¡tÏQn h ts ¡f'wJrv i Well Cores/Samples Infonnation: ADDITIONAL INFORM~N Well Cored? y~ Chips Received? ~ Daily History Received? 0N (ßN Formation Tops Analysis Received? .~ ------ Comments: =~ Compliance Reviewed By: ~ Date: ~q~~-<1ç ~~~<Y'\.~ t\\i:as ~~~ OC'T 1 ç') ?Q03 ',' i_".. "- ''', ,.', c", ",0" r·"I', "t, ::-, i"< rwil'l!'!'1I ·!'thl\1if'l.i'y, ~ðt~:"~1~~:~;'~:d~t~~I~~p~~~edes A~ ~·tn~."" shi"ftecf lTIerged curves. all previous LD\VG tìles tor ,·veIl 5-38A and includes all properly depth :;>''''"Patf~~ F" I ~~~\I E'";; [" " ) 'i'",j Wr""" i ~""' ' t,~ !I>, (II ~ (F~,,~. .... ~:~ \.:.~ ':lì~!:,~~ ~12,f' ""=,'.l'-___ ..... '\¡\""'-- Signed:~)'--~ J{'\ "\~~\~y\ Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 1 LDWG formatted Disc with verification API#: 50-029-22496-70 listing. JaB ) { ~ t{O \- RE: To: MWD Formation Evaluation Logs State of Alaska Alaska Oil and Gas Conservation CorruTI. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 15-38APB 1 AK-MW-30020 October 09, 2003 WELL LOG TRANSMITTAL ) ) fj03 ~-O/ (0 ~~~,Yt~ "'~ Anch':)f(3¡go ;'~~,~,t;~ k,:. '-' :;nmi3~ßon, OCT ~,~<\ ~¡::;, C~· E: ~ \/' Note: This data supercedes shifted merged curves. 1n I \.. t.~ C~ C: ~~) E[J;: all previous LD\VG mes for \Nell 5-38A and 1cludes an properly depth Date: Signe~~~~\~X\ 0,-C~,A.{" Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 PLEASE ACKNOW,LEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 1 LDWG fotmatted Disc with verification API#: 50-029-22496-01 listing. RE: MWD F otmation Evaluation Logs State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 15-38A, AK-MW-30020 To: WELL LOG TRANSMITTAL October 08, 2003 ,,) fjét \(J ) l ~ '~C{ ) ') (Ðð3 --0 , (p Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~e~~18 JUL 24 2003 Afai~:& Gaa Cons. Commission Anchorage N ü te, Signed: ~ it, ; s; DQ, -/q re¡ (Q C Øi; ql1~ prevlovr Ðø..lq BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: LDWG formatted Disc with verification API#: 50-029-22496-01 isting. RE: To: MWD Formation Evaluation Logs State of Alaska Alaska Oil and Gas ConseIVation Comm. Attn.: LisaWeepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 5-38A, AK-MW-2260358 June 02, 2003 \ , WELL LOG TRANSMll"l'AL ) ~D2> - D L(o ~3q ¿ Schlumberger NO. 2772 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 05/08/03 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~ Receiv0~ Color Well Job# Log Description Date Blueline Prints E-02A ,'1 í-/:J Î MEMORY PROD PROFILE 03/15/03 1 E-31A :J..rn-/7 ~ MEMORY PROD PROFILE 08/08/02 1 M-29At':~tJ~9~ PDC & TEMPERATURE 04/15/03 1 F-04A ~ J 00 23097 MCNL 03/02/03 1 H-21 (? (0- U}¡; 23074 RST -SIGMA 01/30/03 1 D.S. 1-32A I~",- I Î. 23083 MCNUBORAX 02/02103 1 D.S. 5-06A Á 5 23056 RST-SIGMA 01/23/03 1 D.S. 7-29B. . ~ì:-\q 23096 MCNL 02115103 1 D.S. 15-38A .~D - I ~ 23089 LINER TOP TIE-IN MGRlCCL 02110/03 1 D.S. 15-48AÄD<.~no 5 23098 MCNL 02/19/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 C.C:.·Ct:'\/I=D r'~~ "t-ï?- Date Delivered: MAY 132006 , . JY' G ·...,.,5 {""-!"IE' ('r.l'j;mi~n Al"1!<I!'o.z \ -~.,.,. \.';d V\.Ít,ij. V"¡h... i.Wi'J. ~ .....~-w~'\G .....lIt ~ And\oraga CD ~-' 1 1 1 1 1 1 1 ¡ --- ~ Alaska Oi: & Gas Cons. Cvmmi3si0n Anchorage Date: Sign APR 2 9 2003 RECEIVED Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 1 LDWG formatted Disc with verification listing. API#: 50-029-22496-70 RE: To: MWD State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska Formation Evaluation Logs 15-38APBl AI(-:MW-2260358 April 17.2003 WELL LOG TRANSMITTAL ) ì ) II éXa 3rOllp ú;L/D l~a3fœ otJ & Gas Cons. Commiss;on Anchorage Date: Si~~ APR 2 9 2003 RECEIVED Sperry-Sun Drilling Semces Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 1 LDWG fonnarted Disc with verification listing. API#: 50-029-22496-01 RE: To: MWD State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska F onnation Evaluation Logs 15-38A, AK-MW-2260358 April 17,2003 WELL LOG TRANSMITTAL ) ) a 03-- Öj lp lo3C¡ of2 4/4/2003 10:49 AM > Pat Archey > Sr. Drilling Engr. > Wk.-564-5803 Cell 240-8035 > PLAN FORWARD > Upcoming sidetrack kick-off depth at 6,800' > 7-5/8 " casing to be run from TD of 7997' in newly sidetracked hole to > surface. Casing will be cemented with top at 5641 '. > > PLUG PLACEMENT - > Set 120' Form-A-Plug with top at 8256' > Set cement plug from 8256' with estimated top of cement at 7420' (100' > cement plug above N-sand) > Circulated up +/- 100 Bbls of cement contaminated mud returns after spotting > balanced cement plug. > > > ACTUAL WELLBORE CONDITIONS > 10-3/4" Surface Casing at 3, 140' > 9-7/8" open hole to 11,340' > Top of NA sand at 7520' > > As discussed, I am requesting to forgo the step of tagging the cement plug > used for the Plug and Abandon of the pilot hole on MPS-01. Details are as > follows: > Tom, > 'Archey, Pat" wrote: Tom Maunder, AOGCC PE Good luck with the remaining operations on the well 20 AAC 25.112 (h) allows the Commission discretion to approve a variance for plugging requirements if the variance provides at least equally effective plugging. The information you have provided is sufficient to demonstrate that the penetrated intervals have been successfully isolated as planned. Your request not to tag the plug is approved. You have requested not to tag the plug since the proposed sidetrack depth is some 600' above the planned top of the plug and it would be your preference not to disturb the fluids remaining in that section of the hole. When the plug was set, you indicated that after pulling above the intended plug depth that contaminated cement was circulated from the well bore indicating that the cement was placed as planned. Further isolation of the pilot hole will be added when the 7-5/8" casing is run and cemented. The planned TOC for that operation is about 1200' md above the window. Pat, Further to our conversations regarding the plugging of the 8-01 pilot hole. You indicated that the intent of the plugs placed was to isolate the respective sand lobes and formations penetrated. You further indicated that essentially the last 3000' md of the well bore was in the OB sand. The cemented plug intervals were designed to cover from 50' below the top of the OB to 100' above the N sand. The form a plug provides additional isolation below the bottom of cement. Subject: Re: MPS-01-203-034-Request to NOT Date: Fri, 04 Apr 2003 10:48:58 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Archey, Pat" <ArcheyPJ@BP.com> Re: MPS-01-203-034-Request to NOT tag cement plug ) tag cement plug ) Form 10-407 Rev. 07-01-80 RBDMS 8Fl MAR 2 Ii Gas GQn~. CQ~II G, {é Anchomge In Duplicate Submit " AlasKa Of; No core samples were taken Brief description of lithology, porosity, '"' CORE DATA fractures, apparent dips and presence of oil, gas or water. MAR Submit core ~~~: (~; E I V ED ~ "\ J-.O!/t. :>- 1 ì 2003 Flow Tubing Press. 28. Hours Tested 3.8 Casing Pressure CALCULATED 24-HoUR RATE OIL-BBL 1,580 OIL-BBL GAs-McF 22,524 GAs-McF WATER-BBL 12.61 WATER-BBL OIL 1 GAS-Oil GRAVITY-API (CORR) Date of Test 3/10/2003 27. Date First Production February 22, 2003 PRODUCTION FOR TEST PERIOD PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing CHOKE SIZE 88.38 RATIO 14,258 2" MD 12740' - 13030' 13250' - 13560' 13690' - 13800' 13850' - 13870' 13890' - 13930' 14020' - 14090' TVD 8929' - 8937' 8938' - 8931' 8930' - 8925' 8925' - 8925' 8925' - 8927' 8931' - 8934' ACID, FRACTURE, DEPTH INTERVAL (MD) 2000' CEMENT SQUEEZE, ETC. AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE GRADE Top BOTTOM SIZE H-40 30' 110' 30" NT80CYHE 35' 3530' 16" NT80S 30' 9420' 12-1/4 NT95HS 9277' 11586' 8-1/2" L-80 11447' 125271 6" L-80 9960' 141421 3-3/4" 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) Gun Diameter, 4 spf MD TVD 26. 4-1/2" SIZE 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9997' PACKER SET (MD) 9935' 23. CASING SIZE 20" 13-3/8 9-518" 7" 4-1/2" * WT. PER FT. 91.5# 68# 47# 29# 12.6# 8.81# / 6.2# / 6.16# CEMENTING RECORD 260 sx Arctic Set (Approx.) 1175 sx PF IE', 375 sx Class 778 sx Class 'GI 409 sx Class 'GI Isolated Slotted Liner 127 sx Class 'G' 'G' 3-1/2" x 3-3/16" x 2-7/8" AMOUNT PULLED ADL 028309 2. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 1/31/2003 2/8/2003 2111/2003 17. Total Depth (MD+TVD) 'I 18. Plug Back Depth (MD+TVD) 119. Directional Survey 14142 8937 Ft 14109 8935 FT 1m Yes 0 No 22. Type Electric or Other Logs Run DGR, MGR, CCL 5. 4. 196612 Location of well at ì 1458' SNL, 7991 I I :C. 22, T11 At top of product 'I val 972' SNL, 4486' I I :C. 27, T11 At total depth 2257' SNL, 4986' : IEC. 27, T11 Elevation in feet ( IIt'U",...h... I RKB = 66.05' 115. Water depth, if offshore N/A MSL 20. Depth where SSSV setl21 (Nipple) 2228' MD 7/wJ~ Thickness of Permafrost 1900' (Approx.) / .:z~ 7~S--;n.Þ ~932111/Þ I 16. No. of Completions One N, R14E, UM i"'~:"''''·'''' KB, DF, etc.) 6. x = 681078, Y = 5954065 Lease Designation and Serial No. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 11 15-38A N, R14E, UM N, R14E, UM x = 680546, Y = 5955337 10. Well Number ,/ ~ ,-2::--lälb~ j :,'F::,I' ì..--..q¿' , 9 '~-"''''''''¡--''J\!J'" ......., "", . - ,~ . X = 676737, Y-:'S960042 Unit or Lease Name Prudhoe Bay Unit I STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~,..'., 1~\ãI!>_~"·~""'/. ~ t<..'tCA1iON$i I ,~ ~, ~~,R,' ~, .. s' " ", OS ,:è¡;íJ, '¡ ..~ ervlce ~ " j'L ? ' ·,.I'.')~' _;"":'::~~_ .'. ~!..:' r:1:r::~:·""'::o::'~''';'····:'·':' 3. Address P.O. Box Anchorage, Alaska 99519-6612 8. API Number 50- 029-22496-01 2. Name of Operator BP Exploration (Alaska) Status of Well IS! Oil 0 Gas o Suspended Inc. o Abandoned 7. Permit Number 203-016 1. ) Classification of Service Well Form 10-407 Rev. 07-01-80 ITEM 28: If no cores taken, indicate 'none' lEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 21 Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 16 AND 24: producing intervals pertinent to such interval. If this well is completed for for only the interval separate production reported in item 27. Submit from more than one interval (multiple completion), so state in item 16, and in item 24 show the a separate form for each additional interval to be separately produced, showing the data 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 1: Classification of Service Wells: injection for in-situ combustion. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, 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. INSTRUCTIONS Permit No. / Approval No. 15-38A Well Number hereby certify that the f/Oi~9 is Signed Terrie Hubble ~ 0 MJ...t ~ 203-01 6 Title Prepared By Name/Number: Drilling Engineer: Technical Assistant Date Terrie Hubble, 564-4628 Alistair Sherwood, 564-4378 03-. / I ~03 32. 31 List of Attachments: true and correct to the best of my knowledge Summary of Daily Drilling Reports, Surveys Zone 1A 12740' Measured Depth 8929' True Vertical Depth 29. Marker Name Geologic Markers ) Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 30. Formation Tests ) 17:15 - 18:40 1.42 CLEAN P 18:40 - 18:55 0.25 CLEAN P 18:55 - 19:30 0.58 CLEAN P 19:30 - 21:15 1.75 CLEAN P 21:15 - 21:45 0.50 CLEAN P 21 :45 - 22:40 0.92 CLEAN P 22:40 - 23:10 0.50 CLEAN P 23: 1 0 - 23:20 0.17 CLEAN P 23:20 - 00:00 0.67 CLEAN P /31/2003 00:00 - 00:50 0.83 CLEAN P 00:50 - 01 :05 0.25 CLEAN P 01:05 - 01:15 0.17 CLEAN P 01:15-03:10 1.92 CLEAN P 03:10 - 03:30 0.33 CLEAN P 03:30 - 04: 1 0 0.67 DRILL P 04: 1 0 - 06:05 1.92 DRILL P 06:05 - 07:10 1.08 DRILL P 07:10 - 07:30 0.33 DRILL P 07:30 - 08:50 1.33 DRILL P PROD1 PROD1 DECOMP DECOMP DECOMP PROD1 PROD1 PROD1 DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 1/30/2003 00:00 - 00:30 0.50 MOB P PRE 00:30 - 00:45 0.25 MOB P PRE 00:45 - 02:30 1.75 MOB P PRE 02:30 - 04:30 2.00 BOPSUR P DECOMP 04:30 - 09:30 5.00 BOPSUR P DECOMP 09:30 - 11 :00 1.50 CLEAN P DECOMP 11 :00 - 11 :30 0.50 CLEAN P DECOMP 11 :30 - 11 :45 0.25 CLEAN P DECOMP 11 :45 - 12:00 0.25 CLEAN P DECOMP 12:00 - 14:00 2.00 CLEAN P DECOMP 14:00 - 14:30 0.50 CLEAN P DECOMP 14:30 - 16:30 2.00 CLEAN N SFAL DECOMP 16:30 - 17:15 0.75 CLEAN N SFAL DECOMP Hang BOP's, prep rig to move from Safety mtg re: move off/on Move rig off 15-15b, wave at N2, spot on 15-38, prep to NU Accept rig for operation at 0230 hrs 1/30/03 ND tree cap, NU BOPE MIRU flowback and cuttings tanks Test BOPE witnessed by AOGCC Rep Chuck Scheve. Meanwhile fill rig pits with 1% KCL-water (with 1# bio & 1# flo-vis). P/U injector. Cut coil. Install DS eTC. Pull test to 35k. Circulate & fill coil. PT CTC & inner reel valve to 3500psi. M/U cleanout BHA #1 with side jetting nozzle, stinger & MHA Stab injector on well. Held pre-operations safety meeting. Review well plan & potential hazards & wellbore cleanout/killing procedures. Open up well & check for pressures: WHP = 613psi, IA = 498psi, OA = 233psi. RIH with BHA #1 to 11500' choking returns to tiger tank. Wt check @ 11500' = 42.5k. Wash down the 4-1/2" slotted liner @ 4.1 bpm/2350psi from 11500' to PBD Tagged @ 12545'. POOH to 8887' circ @ 2.2bpm/1150psi & still getting gassy returns. Call for more KCL water. FLP build up to 500psi - lateral may leaking into wing valve. Call DSO & grease crew to check/grease-lock valves. Park @ 8887' & circ well @ 1.1 bpm. Meanwhile grease lock wing valve & observe 1:1 returns. Bleed IA/OA from 850/450psi to 200/200psi. Grease lock lateral valve, but FL is not bleeding below 150psi as lateral valve is still leaking. Continue POOH circ @ 1.8bpm/760psi. LD CO assy MU milling assy. DS install UTIM RIH w/ milling assy (3.80" D331/SR, motor, jars) Tag XN @ 10017.5' CTD Start pump, stall, corr to 9995' ELMD. Mill thru and dress up 2.7/1660 losing 0.2 bpm RIH. Precautionary ream 4-1/2" liner from 11450' 2.6/1600. Tag Packoff Bushing at 12524'. PUH 37.7k Mill on Packoff Bushing w/ 3 stalls 2.6/1600 losing 0.1 bpm Ease in hole looking for guide shoe while swapping to used Flo Pro mud. Find it at 12546.7' Mill on guide shoe Continue to mill on guide shoe while fin swap to used mud 2.6/2370 full returns. Broke thru at 12550' Ream until clean. RIH from 12550' looking for open hole TD and found it at 12560' Drill 2' to 12562' just to be sure its sand Backream thru jewelry, POOH for drilling assy LD milling BHA. Mill and SR both 3.80" MU drilling BHA RIH w/ BHA #3 (1.04 deg motor, 4-1/8" bi bit) Log GR in the 7" LNR from 11320' & tie-in with Geology PDC log. Subtract 32' from CTD. Test orienter - geting 1 :1. Continue RIH BHA#3 to TO tagged @ 12556'. Begin drilling. Geo wants to land earlier than planned to get Printed" 2/1712003 23032 PM 5-1 5b Legal Well Name: 5-38 Common Well Name: 5-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 " ) 2/1/2003 00:35 23:40 23:50 00:00 23:05 00:20 - 00:35 23:50 00:00 00:20 23:40 01:00 0.42 0.25 0.58 0.17 DRILL 0.17 DRILL 0.33 DRILL DRILL DRILL DRILL P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD Printed: Wiper to window Drilling 2.5/2900/145L-90L to hold 90 deg in high P rate area (120-160'/hr), but GR is still 100-200 api. Drill to 13174' Wiper to check GR and repeats in 12740-800' area. Continue wiper to shoe Orient to build to 95 deg Drill to 13194' Drill from 13194-13218' 2.6/2900/21L 120-160'/hr and GR still showing shale. Geo wants to head up at 95 deg Not comfortable w/ GR readings-drilling too fast for shale. Wiper to 12860' 2.6/2900 Relog GR from 12830-12780'-tracked previous GR w/ a few 2/17/2003 2:3032 PM 22:00 22:40 22:40 23:05 0.67 DRILL 0.42 DRILL P P PROD1 PROD1 Drilling 2.6/3000/130L to 1 to bottom. Got in some faster the mother lode 19:45 - 20:10 20:10 - 20:20 20:20 - 20:45 20:45 - 22:00 0.42 DRILL 0.17 DRILL 0.42 DRILL .25 DRILL P P P P PROD1 PROD1 PROD1 PROD1 19:00 19:30 18:00 14:20 - 14:35 14:35 - 16:00 6:00 8:00 2:20 2:40 11 11 09:50 08:50 - 08:55 08:55 - 09: 15 09:15 - 09:40 more lateral & prevent possible TD extension. Drill to 12617' with 165R TF, 2.5/2.5bpm, 2850/3000psi & 45fph ave ROP. Pump up 1 st good survey. Orient TF to 135R. Drill to 12659' with 110-120R TF, 2.5/2.5bpm, 2850/3250psi & 105fph ave ROP. Orient & drill to 12676' with 90-30L TF, 2.5/2.5bpm, 2850/3250psi & 100fph ave ROP. Seems like we're crossing a fault with +/-200degs reactive. Reorient to 110-120R & drill to 12691' with 110-120R TF, 2.5/2.5bpm, 2850/3250psi & 90fph ave ROP. Drill to 12700' with 100R TF, 2.5/2.5bpm, 2850/3350psi & 110fph ave ROP. Wiper trip clean to shoe. RBIH. Drill to 12756' with 80-90R TF, 2.5/2.5bpm, 2850/3350psi & 75fph ave ROP. eactive back to normal. Drill to 12787' with 90R TF, 2.5/2.5bpm, 2850/3150psi & 110fph ave ROP. Drill to 12830' with 75-90R TF, 2.5/2.5bpm, 2850/3250psi & 63fph ave ROP. Stacking wt. Wiper trip clean to shoe. RBIH. Drill to 12900' with 70-90R TF, 2.5/2.5bpm, 1900/3250psi & 70fph ave ROP. Orient TF to 70L. Drill to 12948 with 70-80L TF, stacking weight Wiper to 10100' to reach 60 degree hole angle for clean up, ordered trucks for mud swap Resume drilling. Pit vol=262 bbls. Free spin 2.5 @ 2950 psi. ROP significantly improved by wiper trip. Now making 90 fph. IA and OA bled down. Current IAP=550 psi, OAP=285 psi. Drill to 12995' and stacking bad and land at 8900' TVD as planned Wiper to shoe while wo mud Drilling 2.5/3500/35L building from 84 deg to level out and look for sand. Drill to 13012' Wiper to 12700' while start new mud Drill from 13012' w/ new mud to 13034' Orient around 3120' and have trouble getting back drilling at 13110' and assume it's 19:30 9:45 9:00 0.50 DRILL 0.25 DRILL .00 DRILL 0.25 DRILL 1.42 DRILL 2.00 DRILL P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 09:40 30 5 0:20 0:30 10:10 - 10:15 0:10 09:50 12:40 14:20 11 10:30 11 :15 2:20 :30 0.33 DRILL 1.67 DRILL 0.83 DRILL 0.25 0.08 0.17 DRILL 0.75 DRILL 0.33 0.17 DRILL 0.08 DRILL 0.33 DRILL 0.42 DRILL DRILL DRILL DRILL P P P P P P P P P P P P PROD1 PROD1 PROD1 PROD PROD1 PROD1 PROD1 PROD1 PROD PROD1 PROD1 PROD1 1/31/2003 07:30 08:50 .33 DRILL P PROD1 Legal Well Name: Com man Well Name Event Name: Contractor Name: Rig Name: 5-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 )1 ) 0:15 - 10:30 0.25 DRILL P PROD1 0:30 - 11 :25 0.92 DRILL P PROD1 11 :25 - 11 :45 0.33 DRILL P PROD1 11 :45 - 12:50 1.08 DRILL P PROD1 12:50 - 13:00 0.17 DRILL P PROD1 13:00 - 13:20 0.33 DRILL P PROD1 13:20 - 13:30 0.17 DRILL P PROD1 13:30 - 14:40 1.17 DRILL P PROD1 14:40 - 15:20 0.67 DRILL P PROD1 15:20 5:50 0.50 DRILL N DPRB PROD1 5:50 6:20 0.50 DRILL N DPRB PROD1 6:20 6:40 0.33 DRILL N DPRB PROD1 6:40 7:05 0.42 DRILL N DPRB PROD1 08:00 02:15 03:45 04:30 06 :45 0:15 03:45 04:30 06:45 08:00 2.25 1.50 DRILL 0.75 DRILL 2.25 DRILL 1.25 DRILL DRILL P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 Printed. minor anomalys Wiper to EOT at 10000' inside 4-1/2" liner POOH to change GR probe and bit Change GR probe and bit. Bit was 0-0-1 RIH wI BHA #4 SHT 12410', Log tie in pass up. IAP=252 psi, OAP=234 psi. Free spin=2640 psi at 2.3 bpm. Make -56' correction! RIH to MAD pass over bottom 150 of hole. Set down several times at 12990'. Finally made it thru, set down again at 13180'. Seems to be bottom. This is 30' shallow of last tag??? Need to make MAD pass to check GR accuracy, will also log up enough to tie in to previous run. GR charecter is identical to last run. Confirms that this is shale. Found depth descripency. Geo deciding which tie in to use. Add 36' back in to get on depth. Total correction from when we first RIH is now -20'. Orient to 45L. 13219', Resume drilling. Free Spin=3050 psi at 2.6 bpm. Drilling at 3200 psi, 2.6/2.6. Pit vol=265 bbls. 13259', INC at bit now 95 deg. Orient to hold angle. Drilling up trying to reduce TVD by 25 TVD feet to find target sand. Resume drilling. 13296', Current INC=94 deg. Orient to raise build angle to 95/96 deg. Resume drilling. Orient to 80L to hold angle. Resume drilling. 2.5/2.6/3290 psi. Pit vol=263 bbls. 13369', 139' since last wiper. Weight transfer getting a little sticky, make wiper trip. Hole sticky off bottom. Started pulling heavy at 12615', getting a slight amount of motor work, but no packing off. Had to back ream up to 12582'. Tagged up hard at this depth. We should be 27' inside liner with the CTC, based on ELM tie in depth. Note, there were significant depth descrepencies from earlier tie ins. It is not out of the question that the CTC is just at the casing shoe. Try to pull up into casing multiple times. Tag up hard each time at the same depth. Got stuck a few times, but managed to get free going down. Unable to come up through guide shoe. Try orienting to get a different angle on the dangle. Call for driller to mix a high vis sweep. Tried 5 clicks on orienter, pulled up, tagged up at same spot. Repeat. No success. Should be 200 degrees from tool face when originally tagged up. 100% returns thruout operations. Pump 5 bbls of high vis sweep, then follow with 10 bbls of water. Pump at highest rate possible with motor, 3.0 bpm and 4100 psi CTP. Pumped as we pulled into tight spot, and worked it up and down. No packing off, no sticking, 100% returns. Unable to get free. Hard tag at 12582'. No motor work while pulling up or at tag up. 12582', Try the orienter trick again. Drop down, orient 5 clicks, pull up into tight spot. Repeat for 360 degrees. No success. Try pulling up into tight spot and taking clicks. No success. 12576' (Pipe stretch) Drop down and pull to max safe tension 2/17/2003 2:30:32 PM 2/1/2003 00:35 01:00 01:00 02:15 0.42 1.25 DRILL DRILL P P PROD1 PROD1 Sticky wI motor work first 200'after Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 15-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) '} 18:25 8:50 0.42 DRILL N 18:50 9:20 0.50 DRILL N 19:20 9:45 0.42 DRILL N 19:45 - 20:20 0.58 DRILL N 20:20 - 21 :00 0.67 DRILL N 21 :00 - 21 :40 0.67 DRILL N 21 :40 - 22:00 0.33 DRILL N 22:00 - 22:45 0.75 DRILL N 22:45 - 00:00 1.25 DRILL N 2/2/2003 00:00 - 00:15 0.25 DRILL N 00:15 - 00:30 0.25 DRILL N 00:30 - 00:50 0.33 DRILL N 00:50 - 02:40 1.83 DRILL N 02:40 - 03:20 0.67 DRILL N 03:20 - 03:30 0.17 DRILL N 03:30 - 04:00 0.50 DRILL N 04:00 - 04:10 0.17 FISH N 04: 1 0 - 04:50 0.67 FISH N 2/1/2003 6:40 - 17:05 0.42 DRILL N DPRB PROD1 17:05 - 17:40 0.58 DRILL N DPRB PROD1 17:40 - 18:25 0.75 DRILL N DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed' 90klbs. Can not pull thru tight spot. BHA now stuck, can't move up or down. Returns still 1 for 1. Pit vol=262 bbls. Notify town of situatoin. Call DS base for cement pumper to pressure up disconnect ball if needed. Check with BHI and Sperry to check about acid tolerance. Both are ok with pumping 15% HCL if needed. Talk to DS Base. They are on standby to pump acid if needed. Waiting on town for orders. BHA popped free with weight stacked on it. . Ran in the hole easy, saw no motor work. Pick up, made it to 12562' (Pipe stretch) before tag up. Continue to pull up into it at same depth several times. Solid depth, not moving. Mix and pump 30 bbls very high vis sweep. Pump same. RIH to TD, clean. Tag at 13357' and correct to 13369' (+12) PUH 37.8k and orient 180 deg while PUH to shoe. Rather sticky thru 12980-13030' on pull back thru Log tie-in up from 12780' 2.6/3260/25R. Corr -8' PUH to shoe. PUH 38k 2'/min from 12610' 2.6/3260/31 L. Get to 12600' bit (BHA = 65.3', shoe assumed to be at 12544') and start pulling 5k over, sticky trying to go down. Work slowly up using 6k over max while continuing to circ w/ full returns and occasionally RIH to ensure not stuck. Assume clay cuttings are sticking BHA at CTC in 4-1/2" liner 12585' 44k 2.3/2870/13L 12580' 44k 2.3/2820/1 OL 12577' 44k Start 13 bbl SAPP (clay remover/thinner) w/ Klagard pill 2.4/2940/4L down CT Park at 12600' and circ 3 bbls SAPP at 0.5/1260, then let it soak. Pull uphole in 5' stages while letting SAPP soak and pumping in 1 bbl stages-definitely improved wt transfer in down mode. Got to 12576' w/ normal up wt. After pill gone, try one time and get to 12557', incl 92.4 deg Attempt to RIH and stuck in down mode. Circ w/ wt stacked to free up BHA before proceeding to disconnect in OH 2.4/3000/95L Get free in down mode in high gear. RIH freely to tie-in 2.1/2750 Log tie-in up from 12780' while wo second DS pump truck (first one had another job). Corr -1' Orient to 180 deg out of drilled TF to 142L Park at 12840' (148L). Circ 0.4/1250 while wo DS pumper RU DS pumper. Chk TF 2.6/3440/142L at 80.4 deg incl Safety mtg re: hi press Park at 12845'. Load 15/16" steel ball. Circ to seat w/ rig mud pump 2.6/3550/133L. Ball seat sheared at 4000 psi 2.0/2200, 1.7/1650. Disconnected from BHA leaving bit at 12845' and FN at 12782' (to leave enough room to set OH WS and KO in target sand at 8870' TVD in case fishing unsuccessful). RDMO DS pumper PUH 32k. Flag CT at 12600' EOP (12665.3' bit). 2.4.2130 Pull into shoe 4.3/3760 at 20'/min 32.2k and started pulling heavy at 12580' (still bit depth). PUH w/ autodrill at 0.2'/min while jetting clayball w/ rate. Get to 12568' at 44k. Able to go down, but sticky 2/17/2003 23032 PM Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 15-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ') 2/2/2003 04:50 - 06:30 .67 FISH N PROD1 06:30 - 07:20 0.83 FISH N DPRB PROD1 07:20 - 07:40 0.33 FISH N DPRB PROD1 07:40 - 09:20 1.67 FISH N DPRB PROD1 09:20 - 11 :20 2.00 FISH N DPRB PROD1 11 :20 - 14:00 2.67 FISH N DPRB PROD1 14:00 - 14:30 0.50 FISH N DPRB PROD1 14:30 - 15:50 1.33 FISH N DPRB PROD1 15:50 - 17:45 1.92 FISH N DPRB PROD1 17:45 - 18:25 0.67 FISH N DPRB PROD1 18:25 - 19:20 0.92 FISH N DPRB PROD1 19:20 - 20:00 0.67 FISH N DPRB PROD1 20:00 - 20:25 0.42 FISH N DPRB PROD1 Printed' Enter 4-1/2" liner and precautionary ream 20-25'/min w/ minor motor work, but no set downs Lost wt at 12541' CTD and stall 2.5/2550 34k, 16k Lost wt at 12545' and motor work, slow ream to 12549' and stall. Temporarily immobile both directions. Pull free at 78k. Ream back down, clean 12560' motor work, then clean to 12563'. Assume mill is at shoe based on prior corrections. Wiper to 12500' 2.5/2670 (adding Flo Vis) 10'/min 36k 2/17/2003 23032 PM 12567' Circ at 3.4/2840 w/ 12k bind (44k) while cuss 'n discuss. Work back in hole occasionally. CTC is 40' inside 4-1/2" shoe joint at 44k. WOO Changeout, call town, talk to MI, review options. Currently still stuck in hole. IAP=872 psi, OAP=568 psi. Plan forward is; Plan A - Pump an additional MI SAP sweep to break up clay if that is sticking mechanism, Plan B - Pump 15% HCL sweep to break up aluminum debris from shoe if that is sticking mechanism, Plan C - Cut coil and pump down an eline chemical cutter if that is sticking mechanism. Safety meeting with rig crews to inform them of plan forward, to review safety aspects of each operation, and to discuss mitigation of hazards. Action item from safety meeting - need shower trailor on location for hazardous chemicals used in plans A, B, C. Will get from DSM. Transport more SAP from MI, mix 30 bbl pill. 12569', Pump 30 bbl SAP pill, chase with mud. Displace to end of pipe, slow rate to 0.2 bpm, displace SAP pill from coil at slow pump rate while working pipe. Get stuck slightly each time we pull into tight spot. It releases after stacking weight on it. Pulling a maximum of 45 klbs each time we pull into it, which is 10 klbs over normal weight. The tight spot appears to move up the hole about 6" each time we hit it. After 30 cycles we managed to get it moving up hole. Pulling heavy, but definately moving. Pulling slowly. Continue POH pumping 3 bpm, and pulling slowly. At 11642', started getting grabby again. Something still above us? Drop down and work back up. Got thru it on second attempt. Tag up at surface, recovered BHA down to disconnect, as expected. Some obvious signs of damage or marking on top of CTC. Deep gouges running up and down eTC. No marks on coil tubing. Very small amounts of clay on CTC and NRJ, but not enough to be conclusive. SWS hands report that the marks were not on the CTC when it was run in the hole. Suspect that the cause of sticking was debris/fish above the CTC. Install Baker eTC. Pull test CTC to 38 klbs. PT to 3500 psi. Make up 3.80" mill and string reamer, Baker motor, Daily up jars, dual Baker disconnects, 2 jts of PH6. RIH with cleanout BHA. BHA #5. Drop out of Tubing tail, kick on pumps to 2.5 bpm. Free spin = 2450 psi. RIH slowly at 30 fpm to ensure that there is no junk in 7". Legal Well Name: Common Well Name: Event Name: Contractor Name Rig Name: 15-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: Rig Release: Rig Number: 1/30/2003 2/11/2003 Spud Date: 8/9/1994 End: 2/11/2003 ) ,) Printed: 2/17/2003 2:3032 PM 2/3/2003 9:15 8:30 11 08:35 05:30 - 06: 1 0 06:10 - 07:35 07:35 - 08:15 23:00 - 23:45 23:45 - 00:00 00:00 - 01 :40 01 :40 - 02:20 22:00 - 22:35 21 :30 - 22:00 04:00 02:20 22:35 5:00 5:45 10 0:50 08:15 3:30 05:30 04:00 23:00 21 08:35 11 15:00 0:50 3:30 9:15 5:45 8:30 30 o 2.25 STKOH C 0.75 STKOH C 2.75 STKOH C 2.33 FISH 2.25 FISH 0.75 FISH 0.25 FISH 1.67 FISH 0.67 FISH 0.58 FISH 0.50 FISH 0.33 FISH .67 FISH 0.42 FISH 0.67 FISH 1.42 FISH 0.67 FISH 0.33 FISH 0.751 STKOH C .50 FISH 50 FISH N N N N N N N N N N N N N N N N N DPRB DPRB DPRB PROD1 DPRB PROD1 PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB DPRB DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB DPRB PROD1 DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RIH 3-8'/min in open hole Backream to 12500' Wiper to 7" while backreaming. Hung up at 11835' 58k, motor stalled. Work to go down for 25 min Work in up mode and came free at 65k first pull. Start motor and PRS. Continue wiper up (albeit slower) and stalled motor at 11757'. Resume wiper up at 15'/min. Pull into 7" to 11300', clean RIH precautionary reaming 7" and 4-1/2" liner 2.4/2580. 11757', clean. 11835', clean 2k set down at 12187', PU, clean, ream by w/ no motor work, RIH, clean to 12600' Wiper to 7" while backreaming 30'/min 34.2k 2.5/2700, clean POOH Continue POOH w/ mill/motor LD cleanout BHA. Mill/SR both 3.80" w/ no obvious scars. MU WF Venturi JB BHA RIH w/ BHA #6 (to clean up any WL shear stock or perf debris that hasn't been milled up) Start Hoover at 9950' 1.9/4000 30'/min. 2k wt loss at 12167', 12195'. Slow down to 15'/min last 100' and call it good at 12600' CTD 2.0/3540 Hoover OOH 2.2/3950 15-30'/min to 11400' POOH Tag up at surface. Dump venturi basket. Found very little debris, basically only 2 small pieces of rubber about the size of a pencil eraser. IAP=644 psi, OAP=514 psi. Unchanged since yesterday. Pit vol=200 bbls. Make up fishing BHA. GS Spear, Up/Down jars, 2 jts PH6, Accelerator, Dual disconnects. RIH with fishing BHA. No problems or weight bobbles while running down thru tubing, 7" casing, Run thru window slick. Tagged up at 12600', then popped thru. RIH smooth. Top offish at 12782', ELM depth. Typical corrections have been -30'. Stop at 12740' for weight check. Weight up = 35klbs. RIH with pumps on at 0.8 bpm. No significant weight bobbles observed. RIH to 12850', no indication. PU at 37500 Ibs. 1500 Ibs more than weight check. Possibly have fish. RIH dry. Run down to 12900'. PU and are pulling 40klbs this time. Probably have it. POH to check for fish. Pumping accross the backside to keep the hole full. Did not see any weight bobbles at the shoe. Pulled smooth into liner. Tag up at surface. Stand back injector. Check for fish. Found fish engauged by GS Spear. All recovered ok. Rig down fishing eq. Lay down last drilling BHA. Make up WF OH Aluminum bridgeplug set up for 4.125" OH. RIH with WF OH Bridge plug. 2k wt loss at 12163'. Corr -29' at flag. RIH to set depth Load 5/8" steel ball and circ to seat. Pressure up to 4600 psi and set OH WS with top at 12730'. Bleed down press. Stack 3k to verify PUH 32k, clean POOH w/ setting assy 20:50 21:30 0.67 FISH N DPRB PROD1 2/2/2003 20:25 - 20:50 0.42 FISH N DPRB PROD1 from 2563' to 2600' CTD clean Legal Well Name: 15-38 Common Well Name: 15-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ) ) Legal Well Name: 15-38 Common Well Name: 15-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 2/3/2003 21 :30 - 22:00 0.50 STKOH C 22:00 - 22:40 0.67 STKOH C 22:40 - 23:25 0.75 STKOH C 23:25 - 00:00 0.58 STKOH C 2/4/2003 00:00 - 01 :40 1.67 STKOH C 01 :40 - 02:00 0.33 STKOH C 02:00 - 02: 1 0 0.17 STKOH C 02:10 - 03:00 0.83 STKOH C 03:00 - 04:30 1.50 STKOH C 04:30 - 04:50 0.33 STKOH C 04:50 - 05: 15 0.42 STKOH C 05: 15 - 05:30 0.25 STKOH C 05:30 - 05:40 0.17 STKOH C 05:40 - 06:00 0.33 STKOH C 06:00 - 06: 1 0 0.17 STKOH C 06: 1 0 - 06:30 0.33 STKOH C 06:30 - 07: 15 0.75 STKOH C 07:15 - 09:40 2.42 STKOH C 09:40 - 09:50 0.17 STKOH C 09:50 - 12:00 2.17 STKOH C 12:00 - 12:10 0.17 STKOH C 12:10 - 12:20 0.17 STKOH C 12:20 - 14:20 2.00 STKOH C 14:20 - 14:45 0.42 STKOH C 14:45 - 15:20 0.58 STKOH C 15:20 - 15:50 0.50 STKOH C 5:50 6:35 0.75 STKOH C 6:35 6:50 0.25 STKOH C 6:50 7:30 0.67 STKOH I C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed: LD setting assy MU drlg BHA Install DS CTC. RIH w/ BHA #9 Continue RIH w/ BHA #9 Corr -28.9' at flag. PUH 34.6k to 12620' 2.5/3250/63L. Log up from 12620' and tie-in to GR at 12583'. Add 1.0' Precautionary ream in hole to 12700'. Tag WS at min rate at 12731 '. PUH 34k, start motor 2.6/3300/31 L Ream from 12715' 2.6/3280/31 L 1 '/min 20.3k. First motor work at 12731', stall. Begin time drilling from 12730' 2.6/3300/31L 0.1'/2 min. Then use 'Duerr-drill' from 12731' 12731.5' 2.6/3300/40L 12732.4' 2.6/3300/43L Appear to be off-feed CT @ 0.1 '/2 min 12734' 2.6/3330/40L 0.1 '/min Aluminum shavings in cuttings 12738' 2.6/3280/40L O.4'/min 12745' 2.6/3310/45L Wiper to 12700' 34.2k, clean. Orient 1 click Drilling 2.5/3200/40L 70'/hr Noticeable difference of poorer wt transfer w/ aluminum shavings in hole 12771' Wiper to 12700', clean Orient around Resume drilling. Free spin =3000 psi @ 2.5 bpm. IAP=640, OAP=484 psi. Pit vol = 250 bbls. ROP=75 fph. TVD=8864, Planning to land at 8870', in sand as per Geo. 12818'. Wiper trip to T.Tail. Precautionary trip to check ¡fwe are getting good hole cleaning. No sign of any overpulls at OH whipstock, liner guide shoe, in slotted liner, or at tubing tail. On way back in hole MM plugged off. Found large ball of aluminum cuttings. Most likely from the OH whipstock. Orient 2 clicks. Resume drilling. Free spin 3200 psi at 2.5 bpm. TF=25L. ROP=80 fph. Drill solids were 0.8% at midnight. Called for new mud. 12871', Wiper trip to shoe. 12873', Resume drilling. Weight transfer still poor, and we are stacking weight. Continue drilling, pump hi viscosity sweep to try to clean hole to improve weight transfer. 12903', Orient to 30R Resume drilling. 12920', wiper trip to shoe. Clean PU off bottom at 39 klbs. Clean in open hole, thru whipstock, and thru liner guide shoe. Pull 200' up inside slotted liner. No problems with overpulls out or back in. Also doing mud swap to new mud. Resume drilling. We have mud arround and our WOB has very significantly improved. From -15000 Ibs and 30 fph to 8500 Ibs and 100 fph. I love new mud. Note that this mud system has 3% lubtex, 2% flolube and 12 #/bbl clayguard. 12940', Getting a big reactive torque now. It went from 30 deg to 130 deg. May be crossing a fault? Wasn't one here on original hole. Pickup and orient to hold 80R. Resume drilling. 2.6/2.6/3200 psi. Free spin is 3000 psi. PT 32k, 3500 psi. nstall 2/17/2003 2:3032 PM new packoff Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) 10:55 11 :15 10:25 09:30 07:50 06 :45 06:00 06:20 06:20 06:45 0.33 0.42 STKOH C STKOH C PROD1 PROD1 05:00 05:15 04:15 04:30 2/5/2003 02:00 03:00 03:15 00:00 22:30 - 22:45 22:45 - 00:00 19:30 - 21 :45 21:45 - 22:30 9:30 8:30 8:45 7:50 18:25 0.58 STKOH C PROD1 12979', Reactive torq ue seems to be getting better. orient. Resume drilling. 2.6/2.6/3150 psi. Good ROP at 110 fph IAP=620 psi, OAP=525 psi. Pit vol after taking on new mud=279 bbls. 13005', Pick up to take a click. Resume drilling. 2.6/2.6/3250 psi. Up wt = 35K, dwn wt = TF = 80R. Drilled to 13,023'. Drilling, 2.5/2.5 bpm, 3000 - 3500 psi, TF = 90R, 91 deg incl. Drilled to 13050'. Wiper trip to 10,000'. Clean hole. RIH to TD. Drilling, 2.5/2.5 bpm, 3000 - 3500 psi, TF = 90R, 91 deg incl. Drilled to 13080'. Orient TF around. Drilling, 2.5/2.5 bpm, 3000 - 3500 psi, TF = 90R, 90 deg incl. Drilled to 13,130'. Drilling, 2.7/2.7 bpm, 3150/3600 psi, 89 deg incl, Drilled to 13,187' . Wiper trip to Shoe. Clean hole. RIH. Orient TF to high side. Drilling, 2.7/2.7 bpm, 3150/3600 psi, 10R, 96 deg incl, Drilled to 13,260' Orient TF to 80R. Drilling, 2.7/2.7 bpm, 3150/3600 psi, 80R, 95 deg incl, Drilled to 13,290' Orient TF to 180R Drilling, 2.7/2.7 bpm, 3150/3600 psi, 180R, 93 deg incl, Drilled to 13,321'. Orient TF to 80R. Drilling, 2.6/2.6 bpm, 3000/3600 psi, 80R, 93 deg incl, Drilled to 13, 13347', PU clean at 35klbs, Wiper trip to the shoe. Motor work up at 13125'. Pulling at 20 fpm, hung up at 12530'. May have liner loaded up with cuttings. Plan to work it up slowly. Pulled up and hung up at 12512', dropped down and plan to pump a hi vis sweep prior to working it any more. Wait at 12528'. BHA is free. Wait on sweep. Pump at 3.0 bpm while waiting on sweep. Pump 30 bbls high vis sweep. Pull up hole slowly while pumping hi vis sweep around. 100% returns, pulling up, getting thru tight spot ok. Continue pulling slowly, chasing sweep. Got thru previous bad spots, speed up to 35 bpm. At 12005', started seeing overpull again. Obviously chasing something out of the hole. Most likely cuttings. Drop down and come up slowly and got past bad spot. Got thru rest of 4.5" liner ok, pull slick in 7". Made it up to 4.5" liner ok. Run back in hole to finish wiper. No problems while RIH. Plan to pump high vis sweep on each wiper trip and alternate trips to casing shoe and Tubing tail to keep well bore clean. Shales below 13120' were a little ratty on way back in. No motor work, but poor sliding. Wipe back to the shoe 1 more time to clean them up. Much better on next trip back to bottom. Orient to 90L. 13347', Resume drilling. at 2.6 bpm Printed 2/17/2003 2:30:32 PM 07:20 1 1 09:30 07:20 15 :40 0:55 0:25 07:50 0.33 STKOH C 0.42 STKOH C 0.50 STKOH 0.92 STKOH C 0.50 STKOH C 0.58 STKOH .67 STKOH C C C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Free spin 3200 psi 05:15 06:00 04:30 05:00 0.25 STKOH C 0.75 STKOH C 0.25 STKOH C 0.50 STKOH C PROD1 PROD1 PROD1 PROD1 03:00 03:15 04:15 02:00 1.00 0.25 1.00 2.00 STKOH C DRILL STKOH STKOH C C C PROD1 PROD1 PROD1 PROD1 8:45 18:25 18:30 0.25 1.25 2.25 STKOH C 0.75 STKOH C STKOH C STKOH C 0.75 STKOH C 0.08 0.25 STKOH C STKOH C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD 7K. 2/4/2003 7:30 - 17:50 0.33 STKOH C PROD1 Pick up to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ) Printed" Resume drilling. 2.6/2.0/3400 psi free spin. psi. 70 fph. Loosing 0.6 bpm. 13673', 137 bbls in the pits. Need mud. Trucks backed up due to Phase 2 weather conditions. Make wiper trip to shoe to wait on mud. Pulling clean in open hole. No problems thru the shale at 13200-13100'. Very slight overpull at shoe, but no 2/17/2003 2:30:32 PM 08:00 09:45 75 DRILL p PROD1 07:25 07:45 07:05 06:00 2/6/2003 04:40 05:00 00:00 02:30 03:45 21:00 9:45 07:45 08:00 07:25 07:05 2:55 3:05 3:30 4:00 2:35 0.33 0.25 0.33 .08 DRILL 8:10 8:20 7:15 6:40 DRILL DRILL DRILL 7:40 05:00 06:00 02:30 03:45 04:40 21:00 8:10 P P P p 7:40 7:15 3:05 3:30 14:00 16:40 12:55 PROD1 PROD1 PROD PROD 00:00 8:20 9:45 0.33 .00 2.50 DRILL 1.25 DRILL 0.92 DRILL 0.17 DRILL 1.42 DRILL 0.17 0.42 0.50 2.67 0.33 0.50 DRILL 0.42 0.58 3.00 DRILL .25 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL P P P p p p P P P P p P P N P P P SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD PROD PROD1 PROD1 PROD1 PROD1 PROD PROD1 PROD1 PROD1 PROD1 PROD1 13424', Weight ransfer getting poor. Getting difficult to keep weight on bit. Make 100' wiper trip. Resume drilling. Transfer still difficult. Still able to drill at 90 fph. Suspect liner getting loaded up with cuttings again. Problem with rig pumps, need to swap pumps. PU hole 30'. 13455', Orient to 70L. Resume drilling. At 13480', pump high vis sweep. 13490', Wiper trip to shoe. Clean pickup off bottom at 34klbs. Bobbly motor work and weight as we pulled up to 13100' at 15 fpm clean after that. 12540', pulling into shoe, got motor work and overpulls. Drop out of it and pump another 30 bbl high vis sweep to clean up hole. Pulled up thru liner chasing sweep. Run back in hole to resume drilling. Slick down in 4-1/2" liner. Slick down to TO in Open hole. Orient to 80 L. Weather conditions now phase 2. Winds 20 mph, gusting to 40 mph. Resume drilling. Free spin 3200 psi at 2.6 bpm. 2.6/26/3500 psi. Pit vol=225 bbls. 13509'. Getting 130 degrees reactive torque. PU to orient. Schlumberger hardline in reel is leaking. Abort further orienting, PUH to the liner to knock apart and fix. Replace seal in hard line and pressure test OK. RIH to TD. Drilling, 2.7/2.7 bpm, 3600 - 4000 psi, 90L, reactive torque varying from 90-180 deg. Drilled to 13,547'. Drilling, 2.7/2.7 bpm, 3600 - 4000 psi, 90L, 89 deg incl, Stacking wt. Varying reactive torque causing slow ave ROP. Drilled to 13,600 ft. Wiper trip up to 4-1/2" tailpipe at 9997'. RIH. Log tie-in with GR at 12,583'. [-16 ft CTD). RIH to TD. Ream shales from 13100-13200'. RIH to corrected TD of 13584'. Orient TF. Drilling, 2.7/2.7 bpm, 3600 - 4000 psi. Slow drilling. In shale again. Drilled to 13,600'. 13600', Drilling ahead. 2.6/2.6/3800 psi, free spin 3400 psi. String weight -8000 psi, drilling shales. Current weather conditions are phase 2-1/2. winds to 40 mph, heavy drifting snow. Current IAP=400 psi, OAP=170 psi, pit vol=197 bbls. 13646', Drilling break, lost returns. 2.5 bpm in, 0.5 bpm out. Pulled up hole 300', and returns slowly came back. Drop back down. Orient to 80R. Drilling with 3700 2:20 2:35 0.25 DRILL P PROD1 2.6/2.6/3400 psi. Pit vol=245 psi. ROP=50 fph string wt=7500 Ibs while drilling. 13369', Same depth as original hole. All should be P for Planned instead of C for and drill instead of sidetrack. data from here on Change in Scope., 11 :40 2:20 0.67 DRILL p PROD1 PROD1 2/5/2003 11 5 11 :40 0.42 STKOH C Surface Legal Well Name Common Well Name Event Name: Contractor Name: Rig Name: 5-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ) Printed: 2/17/2003 23032 PM 09:10 09:40 0.50 DRILL P PROD1 PROD1 Resume drilling fph. 13846' Too early to tell, but seem to have much better WOB 2/7/2003 08:25 07:50 08:10 04:15 23:30 03:15 03:00 00:00 07:10 07:00 08:15 09:10 08:10 08:15 07:00 00:00 04:15 03:15 03:00 07:50 07:10 08:25 0.75 DRILL 0.17 DRILL 0.17 DRILL .00 DRILL 2.75 DRILL 0.25 DRILL 3.00 BOPSURP 0.50 BOPSURP 0.33 DRILL 0.08 DRILL 0.67 DRILL P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 2.1/2.1/4100 psi. LlO drilling MWD BHA. Bit still on gauge. WOW. Field in Phase 3 conditions, 40-55 mph winds, blowing snow. Crew changeout was very difficult at 1800 hrs. No visibility on pad. 4-10 ft snow drifts. Perform weekly BOPE pressure / function test. Phase 2 conditions called at 23:30 hrs. Performed weekly BOPE pressure / function test. Jeff Jones waived AOGCC witness. Sent BOPE test report to AOGCC. SAFETY MEETING. Review BHA M/U procedure, hazards and mitigation with crew. M/U MWD BHA #10. 1.04 deg motor and re-run DS49 bit. Also ran Agitator tool as second test on tool. RIH with BHA #10. Shallow test tools. Check orienter. RIH. No problems or weight bobbles running down thru 4-1/2" slotted liner. Log tie in pass up from 12640' bit depth, CTM. Make -31' correction, which is consistent with previous tie ins. Continue RIH. There were a few weight bobbles around 13100', but hole conditions have much improved over the last couple of days. Orient to 80R. Tag bottom at 13809', Resume drilling. Free spin=3800 psi at 2.3 bpm. Drilling at 2.3/2.2/4150 psi. Pit vol=316 bbls. IAP=O, OAP=150 psi. Getting 135 degrees reactive torque. Pick up and orient to account for reactive. 31 bbls in pits. Making 70 20:15 23:30 3.25 DRILL N WAIT PROD1 9:40 4:30 4:55 6:30 12:20 12:30 12:35 13:00 13:50 14:00 20:15 - 12:30 - 12:35 - 13:00 - 13:50 14:00 14:30 14:55 16:30 9:40 0.58 DRILL 0.42 DRILL 1.58 DRILL 3.17 DRILL 0.17 DRILL 0.08 DRILL 0.42 DRILL 0.83 DRILL 0.17 DRILL 0.50 DRILL P P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 in good shape, Pit vol=60 bbls. Orient to 80R. 13673', Resume drilling. 2.5/2.2/3700 psi free spin. Drilling ahead at 85 fph. 13715', PU for 100' wiper trip. Resume drilling. PU to orient around to 75R. Resume drilling. 100' wiper trip. Resume drilling. 2.5/2.3/3930 psi. Add an additional 1 00 bbls to the system. Pit vol = 316 bbls. An additional 1 00 bbls of new mud is standing by on the vac truck. 13756', 500' wiper trip to improve weight transfer. Resume drilling. 2.4/2.3/4000, 300 bbls in the pits. POOH for Weekly BOP test. Clean PU off bottom. Smooth in lower section of hole. Grabby from 13180-13100'. Smooth into the 4-1/2" liner guide shoe, smooth in 4-1/2" liner, smooth in 7". chipped cutter 11 :15 11 :45 11 :45 12:20 0.50 DRILL 0.58 DRILL P P PROD1 PROD1 0:35 11 15 0.67 DRILL P PROD1 problems like yesterday. Pull up in 4-1/2" slotted pull into 7" to 11400', no problems. RIH slowly, pumping 0.8 bpm, 0.5 bpm returns, mud. RIH to resume drilling. 230 bbls of recycled mud on location. 09:45 0:35 0.83 DRILL N WAIT PROD1 waiting on 2/6/2003 08:00 09 :45 .75 DRILL P PROD1 iner slick, Legal Well Name: 15-38 Common Well Name: 15-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ') 2/8/2003 00:00 00:30 21:30 9:00 13:35 14:00 14:15 6:50 2:55 3:10 7:30 7:45 5:30 00:30 00:45 00:00 21:30 7:45 9:00 4:00 4:15 5:30 7:30 6:50 3:10 3:35 0.50 DRILL 0.25 DRILL 2.50 DRILL DRILL DRILL DRILL 2.50 DRILL 0.25 DRILL 1.25 DRILL 0.67 DRILL 0.42 0.25 1.25 0.25 DRILL 0.42 DRILL .33 DRILL P P P N P P N P P N P P P PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 RREP PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed' No overpulls in shale at 13200'-13100'. No overpulls at Tubing Tail. Pull up inside of 4-1/2" liner to 12300' slick with no overpulls. Run back to bottom 1 little bobble at 13050', then slick to bottom. Orient to 90R. Resume drilling. 2.2/2.0/4000 psi. Running low pump rates due to higher pressures from agitator tool. Still making decent Rap. 13959', Pick up at 31klbs. Orient around to 75R. Resume drilling. 13969', SPM pump #2 developed a leak in discharge line, swap to pump #1. It is giving erratic pump pulses, seeing noise from Sperry pressure sensor. Pump #1 possibly ready to go down as well. Pull up to 4-1/2" liner to make pump repairs. Clean PU off bottom. Clean thru shale at 13200-13100'. Clean into the liner guide shoe. Standby at surface. Pumps down. Making repairs on both SPM pumps. Repairs completed on both pumps. RIH to resume drilling. On down time until back on bottom drilling. Start mud swap to new flo pro system. Mud contains 3% lubetex, 2%flo lub, 14 #/bbl kla-gard. Set down at 13840' on way in hole. Had to work it last 100' to get to bottom. Orient to 75R. Resume drilling. 2.4/2.4 bpm, 3600 - 3900 psi, 90L, 87 deg incl, Drilled to 14,016'. New FloPro at bit at 14,000 ft. Drilling, 2.4/2.4 bpm, 3400 - 3900 psi, 85L, 87 deg incl. Drilled to 14,100 ft. Wiper trip to shoe. One overpull at 13,160' in shale. Hole looks good. Overpull at shoe, Ream down and pull clean up thru shoe. Wiper up to 12300' clean. RIH. Set down wt in shale at 13,130'. Ream shales from 13130-13200'. RIH. RIH to TD. Orient TF. 2/17/2003 230'32 PM 1 :20 2:55 .58 DRILL P PROD1 0:50 1 :00 09:40 0:00 11 :00 11 :20 0:00 0:50 0.17 DRILL 0.33 DRILL 0.33 DRILL 0.83 DRILL P P P P PROD1 PROD1 PROD1 PROD1 and String weight than yesterday. Easily getting 70 fph in ratty 21 rock. Could be the new Agitator tool. Could also be clean wellbore. Will need to analyze data after we drill and make first wiper trip with cuttings in hole. 13870', Pick up to orient around. Pit vol=308 bbls. Resume drilling. 2.3/2.2/4200. Pit volume=305 bbls. ROP=97 fph. 13928',100' wiper trip. Resume drilling. 2.3/2.2/4140 psi. ROP=66 fph, Pit vol=301 bbls. The SWS driller supports the idea that the agitator tool is working very good from the standpoint of reducing pipe drag. 13943', Wiper trip. Pick up off bottom at 31 klbs. This is 3k to 4k less than yesterday. This may be due to Agitator tool. Need to perform post job analysis of data from yesterday and today. Same mud, as yesterday. Same BHA with the exception of the Agitator tool. 2/7/2003 09:10 09:40 0.50 DRILL P PROD1 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 15-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) } Printed. 2/17/2003 23032 PM 22:00 - 22:20 22:20 - 00:00 0.33 1.67 CASE CASE P P COMP COMP Order Vac trucks for fluid swap, no vac trucks available due to 9ES fluid losses. Will get first 3 trucks available. MIU BKR CTLRT. RIH wI Liner on CT. Circ. at 0.2 bpm, 1500 psi. Pick up at 12,500 ft. Up wt. = 38K, Dwn wt = 20K. 4-1/2" shoe with no wt loss. RIH at 60 fpm, 0.2 bpm, 1400 ps Run thru 18:20 - 22:00 18:00 5:10 5:30 7:35 8:20 15:30 - 17:35 - 18:00 3.67 0.33 0.33 CASE 2.08 CASE 0.42 CASE CASE CASE P P P P P COMP COMP COMP COMP COMP 14:30 5:10 0.67 CASE P COMP Make up Baker CTC. Pull test to 35klbs, PT to 3500 psi. Lay down drilling BHA #10. Tool joints found to be over torqued. Possibly due to vibration of Andergauge tool downhole? Bit recovered in gauge and graded a 1-2-1. PU Baker Deployment tools. Make up proper crossovers TIW valve. Prep to run liner. Safety meeting prior to running liner. Pick up liner as per proceedure. Stop at top of 2-7/8" liner and fill liner. Changeout elevators to 3-3/16" while filling pipe. Note - There are only 3 joints of TCII with in line turbo centralizers available on the slope. The order of 7 joints of centralized TCII, for this well, has not arrived from Unique Machine in Anchorage. Town Engineers notified. Remainder of TCII will be standard wlo turbolizers. Crew change and safety meeting prior to continuing to run liner. Discussed liner job so far, reviewed SOP for liner running. Discussed plan forward, hazards involved, and mitigation. Run 88 Jts of 3-3/16" TCllliner. Total length of Liner = 4.173.64 ft. to 3:00 3:30 - 13:30 14:30 0.50 CASE 1.00 DRILL P P COMP PROD1 12:45 09:30 06:30 02:00 - 04:30 04:30 05:30 08:45 - 09:30 07:10 - 08:45 07:10 05:30 06:30 3:00 2:45 0.25 0.75 2.50 0.67 3.25 .00 .00 58 DRILL DRILL DRILL DRILL DRILL DRILL DRILL DRILL P P P P P P P P PROD1 PROD1 PROD1 PROD PROD PROD PROD1 PROD1 See Remarks Section Drilling, 2.7 I 2.7 bpm, 3200 - 3600 psi, 88 deg incl, 90L, Stacking wt. Clean hole, just difficult to get WOB. Drilling shale. Drilled to 14116'. Drilling, 2.7 I 2.7 bpm, 3200 - 3500 psi, 88 deg incl, 90L, Stacking wt. Unable to get much weight to bit. Slow ROP. Drilling shale. Drilled to 14,150 ft. Called TD due to shale. Wiper trip to shoe. Clean hole. Log Tie-in with GR at 12,583'. Subtract 7 ft CTD. Pull up to 11,320' for cased hole tie-in. RIH for final tag. IAP=300 psi, OAP=200 psi. Pit vol=211 bbls. Tag up at 13080', set down several times from 13080'-13140'. Run down to 13200' ok. Ream up and down thru tight shales to condition hole multiple times until we could pull slick. Continue RIH. Start 30 bbl hi vis sweep to sweep hole prior to POOH. Final ELM corrected tag = 14,142'. Circulate sweep around and POOH for liner. Slick thru 13200-13100'. No problems in 4-1/2" liner. Pulled at 80% in 7" and chased everything OOH. Tag up at surface. Pumped all the way out of the hole. Pit watcher reported large slug of cuttings just before tag up. Found washed out coil connector at surface. Set BHA in slips, cut off SWS CTC. 2/8/2003 00:45 - 02:00 .25 DRILL P PROD1 Legal Well Name: Com mon Well Name Event Name: Contractor Name: Rig Name: 15-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ) ') 02:30 - 06:15 3.75 CEMT P 06:15 - 06:30 0.25 CEMT P 06:30 - 06:55 0.42 CEMT P 06:55 - 08:25 1.50 CEMT P 08:25 - 09:45 1.33 CEMT P 09:45 - 10:00 0.25 CEMT P COMP COMP deg 4-1/2" iner. POOH with Baker procedure. Tag up at surface. Printed: Lay down Baker CTLRT. All 2/17/2003 2:3032 PM recovered ok. 2/9/2003 01 00:20 00:00 o - 02:30 01 00:20 10 33 0.83 0.33 CASE CASE CASE N P P WAIT COMP COMP COMP COMP COMP COMP COMP CTLRT, RIH past open hole whipstock at 12,731' with no wt. loss. RIH at 13,100 ft at 2400 hrs. RIH with liner. Sat down at 13,150',13,200',13,500',13850', 13,900', 13950', 14,030', Tag TD at 14,165' [uncorrected CTD], Pick up with 41.5K, Tag 2 more times at same depth. Liner landed at TD of 14,142' BKB. Top of liner Deployment sub at 9,968 ft. Drop 5/8" steel ball and displace with FloPro. Circ 1.7 bpm at 2200 psi, slow to 0.5 bpm, 1500 psi at 33 bbls. Ball on seat at 41.2 bbls. Sheared at 4100 psi, Pick up free from liner at 27K. Stack down wt and circ. FloPro at 0.5 bpm. Wait on Vac trucks for KCL water. All vac trucks were busy with Rig 9ES fluid loss problem. Finally got 2 vacs available, normally use 4 for a mud swap. Load with 2% KCL water with friction reducer [double slick]. Circ. 2% KCI water, recover FloPro in Tiger tank, due to truck shortage. Circ. 2.5 bpm, 1800 psi. Call out DS cementers and rig up while circ. KCL water. Clean rig pits. Load FloPro and send to MI for re-conditioning. Fill rig pits with 2% KCL water. Circ. KCL water at 2.0 bpm with 1.9 bpm returns. 7% fluid loss. SAFETY MEETING. Review cementing procedure, hazards and mitigation for cementing liner. Circulate while cement is coming up to weight. Cement at weight at 06:50. IAP=O, OAP=150 psi. Pit vol=320 psi. Pump 4 bbls water to warm lines, taking returns to pits thru Baker choke. PT Cementers hard lines to 4000 psi. All pass ok. Come on line with cement. Pumping Class G cement, additives as per proceedure. Pump cement thru MM. It indicates solid 15.8+ ppg cement. Pumped measured 26.0 bbls of cement downhole. Drop dart. Pump 0.2 bbls, check dart away. Dart did not launch. Try again, pressure up to 1100 psi. Attempt to launch dart. Pump 0.2 bbls biozan. Check dart, did not launch. Make adjustments to dart, launch a third time. Confirm dart away. There is 0.4 bbls of biozan below dart. Resume pumping, displacing dart with 30 bbl biozan pill followed by 2% KCL. Land dart 52.9 bbls away (Coil vol=53.4 bbls). Sheared at 3200 psi. Good indication. Displace liner wiper plug to landing collar, getting 100% returns. Started getting packing off at 13.6 bbls cement behind pipe. This corresponds to OH annular volume. Probably debris/cuttings/shale flushed up into 4.5" liner by cement. Only getting 30% returns at 2.5 bpm. Dropped rate to 1.0 bpm, returns came back slowly to 100%. Landed LWP at 81.1 bbls away. Calculated vol=81.8 bbls. Pressured up to 2000 psi. Bled off pressure and checked floats. Floats held. Got 23.6 bbls behind pipe. Lost 2.4 bbls to formation. CIP@08:15. Estimated cement top is 12134', assuming no u-tubing in 94 replacing voidage with biozan as per 2/8/2003 22:20 00:00 .67 CASE P COMP Legal Well Name: 15-38 Common Well Name: 15-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End 2/11/2003 ') ') Weather conditions Phase 2, and access to all WOA pads is restricted due to winds, visibility, and drifting snow. Schlumberger perforating eq stuck in a snowdrift at the entrance to the pad. Hold PJSM with rig crew, SWS memory logger, SWS perforators. Discuss freeing stuck equipment, and plan forward for day. Mobilize rig crew to dig out SWS while Memory Logging engineer compiles log data. Weather Phase 2-1/2. Dig SWS perf gun trailor out of snow drift. SWS perforating eq and personnel are on location to pipe shed, and deployment eq to rig floor. Printed' 2/17/2003 2:30:32 PM Bring guns 06:35 07:15 06:15 07:15 08:15 06:35 0.67 PERF 1.00 PERF 0.33 PERF N N P WAIT WAIT COMP COMP COMP 06:00 03:45 06:15 06:00 0.25 2.25 CLEAN CLEAN P P COMP COMP POH while circ at 2.6 bpm, 2320 psi to cleanout tubing. SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. Phase 2 weather conditions. Stand back CSH in doubles. LlO last 20 jts of CSH in singles Baker rental string ]. Layout Schlumberger memory GR-CCL tool. and mill. lAP = 0 psi, OAP = 150 psi Lay down motor 01 :45 03:30 03:30 03:45 1.75 0.25 CLEAN CLEAN P P COMP COMP 2/10/2003 00:00 23:00 - 00:00 20:00 - 20:30 20:30 - 21 :30 21 :30 - 23:00 5:30 13:15 1 16:05 - 16:15 16:15 - 20:00 15:30 15:05 :20 01:45 6:05 5:05 3:15 .75 0.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 0.17 CLEAN 3.75 CLEAN CLEAN CLEAN 0.58 0.42 .83 .92 CLEAN .00 CLEAN CLEAN P CLEAN P P P P P P P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP PU swizzle stick nozzle. pits from vac truck. Safety meeting prior to running old rig 1-1/4" CSH in hole, then laying out sideways. Strap New CSH on Pipe rack, RIH with used string of Nordic CSH. Continue laying out used Nordic CSH. Weather conditions just went to Phase 2. Remove old Nordic 1 CS Hydril from pipe shed. Pick up SWS memory tools to rig floor. Hold safety meeting prior to picking up cleanout BHA and SWS memory logging tool. Pick up Baker 2-1/8" Motor and SWS memory tool. PU and run 20 joints of Baker 1-1/4" CSH and 120 joints of new Nordic 1-1/4" CSH. Drifting each joint as it's picked up. Also banging the joints with a 3 Ib hammer to ensure there is no loose debris. All were ok. M/U each connection with SWS little jerks to 700 ft-Ibs. M/U DS MHA and CTC. RIH with mill, motor and CSH BHA. Total length = 4391 ft. Log down with SWS memory GR/CCL at 60 FPM from 9800 ft. 30 BBL FloPro perf pill did not reach rig until 2230 hrs, due to Phase 2 conditions. Pump 15 bbl High Vis. FloPro Perf Pill while logging down. 1.0 bpm, 1200 psi. Tag PBTD at 14,128' CTD. Corrected PBTD is 14,107'. Circulate FloPro to bit. Log up from PBTD to 9800' at 60 fpm while laying in FloPro perf pill. Log up with GR/CCL to 9800 ft. Drop 5/8" ball and open circ sub. RIH to to 10,100 ft and POH while circ. at 2.6 bpm to jet top of liner. Phase 2 weather conditions, 30-50 mph wind 11 00 11 :20 0.33 CLEAN P COMP 2/9/2003 09:45 10:00 0:00 1 :00 0.25 1.00 CEMT CEMT P P COMP COMP Wash tree. Load extra 2% KCL into Legal Well Name: 15-38 Common Well Name: 15-38A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ') ) 02:30 - 04:40 04:40 - 05:40 .00 RUNCOI\P COMP 02:00 02:30 2.17 RUNCOJ\fP 0.50 2.75 PERF 2.00 PERF 2/11/2003 21 :15 00:00 19:15 21:00 7:15 9:00 RUNCOI\IP P P 09:55 09:05 08:55 COMP COMP COMP COMP 10:40 12:40 14:30 14:50 16:35 10:30 00:00 02:00 21:00 21 :15 0:30 09:55 09:05 9:00 19:15 2:40 4:30 4:50 6:35 7:15 0:40 1.75 PERF 0.25 PERF 2.00 PERF 1.83 PERF 0.33 PERF 1.75 PERF 0.67 PERF PERF 0.17 PERF .75 0.25 0.58 0.83 PERF 0.17 PERF PERF PERF P P P P N P P P P P P P N WAIT WAIT COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Note weather conditions just declaired Phase 3 on EOA access roads and pads. Consult with ADW Safety officer, ADW Drilling Engineer, perform hazard assessment. Wait on decision to continue with operations. Talk to town. Town geo gives ok to perforate as per email of Feb 8th. Talk to ADW Drilling Engineer. Got OK to continue with operations as long as the Spine road does not go to phase 3 weather conditions. Consult with rig management. SWS team leader, Nordic Toolpusher, BP Co Rep. Hazard assessment. Conclude it is ok to continue operations as long as rig loader can keep access road and path accross pad to rig free for emergency vehicles. Contact SWS management at Deadhorse to confirm. They are ok to remain operating. Contact BP management in Anchorage. Ok to continue working as longs as conditions do not change, and as long as the conclusions of the Hazard assessment are met. Safety meeting with rig crews, SWS perforaters, rig management to discuss Phase 3 weather conditions, plan forward, and decision to continue with operations. Pick up first perf gun. Kick drill. Deploy safety joint. All went ok. Deploy perf guns. Run 96 joints of Nordic 1-1/4" CS Hydril work string. Make up SWS MHA, and injector. RIH with coil. Weight check at 14000=39klbs. Tag bottom 14124' CTM, Pickup at 14117'. Repeat tag. Same depths. Set depth on pickup to ELM tag from logging pass of 14109' (-8 correction based on up weight). Pull into 14091', Pump 17 bbl flopro perf pill. Launch 5/8" ball to fire guns. Confirmed ball rolling. Displace into position with 2% KCL. Ball landed at 47.8 bbls away (Coil + CSH Vol=58.2 bbls). Expected 3200 psi pressure to fire. Got fire at 2800 psi. Slight overpull on pickup. POH with perf guns on coil. SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. Stand back 48 stds of CSH workstring. SAFETY MEETING. Review procedure, hazards and mitigation for recovering fired perf guns and blanks. UO 64 SWS 2" fired perf guns and blanks. All shots fired. Layout SWS 2" Fired Perf guns. Bundle guns and load out of pipe shed. M/U BKR 4.5" KB Liner top Packer and seal assembly with running tools. Total length = 50.57 ft. RIH with BKR 4.5" Liner Top Packer BHA. 120 psi. Up Wt at 9900 ft. = 35K. Printed' 2/17/2003 2:3032 PM Dwn Wt = 24K. Circ. 0.2 bpm at Fax log to town geologist. Continue waiting. Check injectivity down the backside of the liner. Still have injectivity of 2 bpm at 1600 psi. Have retained communication to existing perfs. 2/10/2003 08:15 08:55 0.67 PERF N WAIT COMP Legal Wel Common Wel Event Name: Contractor Name Rig Name: 5-38 5-38A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 Name Name: ) ) Printed. 2/17/2003 230.32 PM WOW standby Wait on Weather. Wind 20-30 mph, too high to pull well house on DS 15-48A. Pad also needs snow removal before rig can be moved. ¡me will be carried on DS 15-48A. 5:00 0.00 RIGD N WAIT CaMP 09:30 10:10 10:30 12:00 10:10 10:30 12:00 15:00 0.67 RIGD 0.33 RIGD 1.50 RIGD 3.00 RIGD P P P P POST POST POST POST RELEASED RIG AT 1500 HRS, 02-11-2003. TOTAL TIME ON WELL WAS 12 DAYS AND 08:30 - 09:00 09:00 - 09:30 08:00 06:10 05:40 - 06: 1 0 06:15 08:30 08:00 06:15 0.50 RIGD 0.50 RIGD 0.50 0.08 0.50 .75 RUNCOIVP RUNCOIVP RUNCOIVP RUNCOIVP P N WAIT POST POST CaMP CaMP CaMP CaMP Sting Seal Assembly in and land with 10K at 9995', P/U at 9990', sting out at 9985'. P/U to 9970' and drop 5/8" steel ball. Circ. 2.3 bpm, 960 psi for 33 bbls. Slow to 0.5 bpm and pump ball on seat at 40 bbls. RIH. Pick up 2 ft . Pump 2500 psi and set slips. Stack 10K at 9992'. Pull5K over OK. Set down 10K, KB Packer is set with top at 9948', ref. SWS Memory GR/CCL Log of 2/10103. Pressure test Packer from back side with 2000 psi for 30 min. Chart pressure test. Good test. No bleed down in pressure. Bleed off WH test pressure. Pressure up to 3700 psi to release from KB packer. Good indication of release. PU crean at 36klbs. Pull out of hole with Baker setting equipment. Pumping neat methanol for freeze protect. FP well from 2000' to surface. Tag up at surface. Stand back injector, lay down Baker deployment tools. All recovered ok. Rig up nozzle, stab on injector for reel blowdown. Waiting on weather for N2 pumper to blow down reel. In transit from Deadhorse in convoy. Rig up N2 pumpers Safety meeting prior to blowing down reel. Blow coil down with N2. Clean rig pits and green tank. RID hardline to tiger tank. Nipple down BOPE. N/U tree cap and press test. Closed master and swab valves. Well secured and freeze protected. 2.5 HRS. 2/11/2003 04:40 05:40 .00 RUNCOIVP CaMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5-38 15-38A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/30/2003 Rig Release: 2/11/2003 Rig Number: Spud Date: 8/9/1994 End: 2/11/2003 ') QI~e.J!øtiø'AS.:SiLJA'1l{111aff··.·ßel'ort BP.·..(£~~b~~~~I~~ -) ,~,..:~ '"' .-. ) ) c/f () <) 07 -Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-38A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,731.68' MD Window / Kickoff Survey: 12,764.88' MD (if applicable) Projected Survey: 14,142.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, RECe\VED William T. Allen MAR 26 2003 Survey Manager A\as\(a on & Gas Cons. eoromiliOn Attachment(s) Ancttorage Sperry-Sun Drilling Services North Slope Alaska BPXA 15-38A ~ Job No. AKMW2260358, Surveyed: 8 February, 2003 Survey Report 6 March, 2003 Your Ref: API 500292249601 Surface Coordinates: 5960042.07 N, 676737.11 E (70017'46.9805" N, 148034' 07.5637" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 66.05ft above Mean Sea Level ~ 5p~""Y-5U" DRIL.l:<ING . SERVICES A Halliburton Company Survey Ref: svy3978 Sperry-Sun Drilling Services Survey Report for 15-38A Your Ref: API 500292249601 Job No. AKMW2260358, Surveyed: 8 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12731.68 80.970 152.730 8861.46 8927.51 4786.81 S 3691.22 E 5955343.39 N 680539.87 E 5898.29 Tie On Point -12764.88 84.410 151.490 8865.68 8931.73... 4815.91 S 3706.62 E 5955314.66 N 680555.95 E 11.004 5931.18- Window Point 12794.41 83.610 149.550 8868.76 8934.81 4841.47 S 3721.07 E 5955289.44 N 680571.00 E 7.073 5960.45 12829.11 84.670 143.910 8872.31 8938.36 4870.32 S 3740.00 E 5955261.05 N 680590.60 E 16.454 5994.60 12859.00 87.220 143.210 8874.42 8940.47 4894.30 S 3757.71 E 5955237.49 N 680608.87 E 8.845 6023.82 -' 12890.28 89.780 144.790 8875.24 8941.29 4919.60 S 3776.09 E 5955212.63 N 680627.84 E 9.616 6054.51 12935.25 92.600 147.440 8874.31 8940.36 4956.91 S 3801.15 E 5955175.91 N 680653.77 E 8.604 6098.92 12969.48 91.450 146.380 8873.10 8939.15 4985.57 S 3819.82 E 5955147.70 N 680673.12 E 4.568 6132.79 13005.78 92.420 149.550 8871.87 8937.92 5016.32 S 3839.07 E 5955117.41 N 680693.08 E 9.128 6168.79 13040.13 92.250 151.840 8870.47 8936.52 5046.25 S 3855.86 E 5955087.89 N 680710.57 E 6.679 6203.01 13070.78 90.040 152.900 8869.86 8935.91 5073.40 S 3870.07 E 5955061.08 N 680725.42 E 7.997 6233.62 13101.80 89.600 156.600 8869.96 8936.01 5101.45 S 3883.30 E 5955033.35 N 680739.30 E 12.012 6264.64 13132.71 87.750 161.710 8870.67 8936.72 5130.32 S 3894.30 E 5955004.75 N 680750.97 E 17.577 6295.45 13161.98 87.490 162.420 8871.89 8937.94 5158.14 S 3903.30 E 5954977.14 N 680760.63 E 2.581 6324.47 13193.68 87.840 166.470 8873.18 8939.23 5188.65 S 3911.79E 5954946.85 N 680769.84 E 12.813 6355.71 13229.48 92.250 165.760 8873.15 8939.20 5223.39 S 3920.38 E 5954912.31 N 680779.24 E 12.477 6390.83 13259.93 95.680 169.640 8871.04 8937.09 5253.06 S 3926.85 E 5954882.80 N 680786.41 E 16.983 6420.45 13290.71 95.420 168.410 8868.07 8934.12 5283.14 S 3932.69 E 5954852.87 N 680792.94 E 4.066 6450.17 13324.96 92.600 171.400 8865.67 8931.72 5316.77 S 3938.67 E 5954819.39 N 680799.72 E 11.984 6483.18 13354.63 91.890 171.050 8864.51 8930.56 5346.07 S 3943.19 E 5954790.21 N 680804.93 E 2.668 6511.65 13384.08 90.040 168.760 8864.01 8930.06 5375.05 S 3948.36 E 5954761.35 N 680810.77 E 9.995 6540.10 13414.00 89.070 164.710 8864.25 8930.30 5404.17 S 3955.22 E 5954732.41 N 680818.32 E 13.918 6569.39 13446.91 91.190 162.590 8864.17 8930.22 5435.74 S 3964.48 E 5954701.06 N 680828.32 E 9.110 6601.92 --/ 13481.96 90.040 157.660 8863.79 8929.84 5468.69 S 3976.39 E 5954668.40 N 680841.00 E 14.442 6636.82 13523.36 88.720 153.250 8864.24 8930.29 5506.34 S 3993.59 E 5954631.16 N 680859.08 E 11.118 6678.20 13563.23 88.190 149.900 8865.32 8931.37 5541.38 S 4012.55 E 5954596.57 N 680878.86 E 8.504 6717.98 13599.00 88.460 145.320 8866.36 8932.41 5571.57 S 4031.70 E 5954566.85 N 680898.72 E 12.821 6753.43 13630.05 91.890 143.910 8866.27 8932.32 5596.88 S 4049.68 E 5954541.97 N 680917.28 E 11.943 6783.96 13662.23 93.130 144.790 8864.86 8930.91 5623.00 S 4068.42 E 5954516.29 N 680936.63 E 4.724 6815.56 13701.30 92.350 149.660 8862.99 8929.04 5655.80 S 4089.54 E 5954484.00 N 680958.51 E 12.609 6854.21 13733.61 92.510 150.790 8861.62 8927.67 5683.82 S 4105.57 E 5954456.36 N 680975.20 E 3.529 6886.38 13767.38 92.950 156.070 8860.01 8926.06 5713.98 S 4120.65E 5954426.57 N 680990.99 E 15.672 6920.09 13796.58 91.630 158.540 8858.84 8924.89 5740.90 S 4131.90 E 5954399.92 N 681002.87 E 9.585 6949.24 13827.55 90.400 161.890 8858.30 8924.35 5770.03 S 4142.38 E 5954371.05 N 681014.03 E 11.521 6980.07 13860.00 88.720 163.650 8858.55 8924.60 5801.02 S 4151.99 E 5954340.29 N 681024.37 E 7.498 7012.22 6 March, 2003 - 10:07 Page 2 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 15-38A Your Ref: API 500292249601 Job No. AKMW2260358, Surveyed: 8 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13890.05 88.190 167.170 8859.36 8925.41 5830.09 S 4159.56 E 5954311.41 N 681032.62 E 11 .842 7041.76 13928.41 88.110 171.580 8860.59 8926.64 5867.76 S 4166.63 E 5954273.91 N 681040.57 E 11 .492 7078.89 13958.66 87.220 175.100 8861.83 8927.88 5897.77 S 4170.13 E 5954243.99 N 681044.78 E 11.993 7107.57 13989.80 86.870 177.220 8863.43 8929.48 5928.80 S 4172.22 E 5954213.02 N 681047.59 E 6.891 7136.57 14025.91 86.700 175.460 8865.46 8931.51 5964.78 S 4174.52 E 5954177.11 N 681050.74 E 4.889 7170.15 14057.86 87.840 173.160 8866.98 8933.03 5996.53 S 4177.68 E 5954145.43 N 681054.65 E 8.027 7200.27 -"' 14094.33 88.020 166.470 8868.30 8934.35 6032.39 S 4184.12 E 5954109.74 N 681061.93 E 18.338 7235.48 14116.18 86.520 164.880 8869.34 8935.39 6053.53 S 4189.52 E 5954088.73 N 681067.82 E 9.998 7256.93 14142.00 86.520 164.880 8870.91 8936.96 6078.41 S 4196.24 E 5954064.02 N 681075.13 E 0.000 7282.32 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 155.000° (True). Magnetic Declination at Surface is 26.028°(30-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14142.00ft., The Bottom Hole Displacement is 7386.17ft., in the Direction of 145.381 ° (True). Comments ~. Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12731.68 12764.88 14142.00 8927.51 8931.73 8936.96 4786.81 S 4815.91 S 6078.41 S 3691.22 E 3706.62 E 4196.24 E Tie On Point Window Point Projected Survey 6 March, 2003 - 10:07 Page 3 of4 DrillQuest 3.03.02.002 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 15-38A Your Ref: API 500292249601 Job No. AKMW2260358, Surveyed: 8 February, 2003 BPXA Survey tool program for 15-38A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 6 March, 2003 - 10:07 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 14142.00 8936.96 MWD Magnetic(15-38) ..~ I -/ Page 4 of4 DrillQuest 3.03.02.002 ') ) (:3) (J ;3,'·-()( tC) 07 -Mar -03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-38PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,463.98' MD Window / Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 13,369.00' MD Please call me at 273-3545 if you have any questions or concerns Regards, William T. Allen Survey Manager RECEIVED Attachment(s) MAR 2 6 2003 A1aIka on & Gas Cons. Comtniseion Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA 15-38PB1 .~ Job No. AKMW2260358, Surveyed: 1 February, 2003 Survey Report 6 March, 2003 Your Ref: API 500292249670 Surface Coordinates: 5960042.07 N, 676737.11 E (70017'46.9805" N, 148034' 07.5637" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 66.05ft above Mean Sea Level ~ SpE!r'r"'Y-SUI'1 DRILLfNG SERvfc::es A Halliburton Company Survey Ref: svy3977 Sperry-Sun Drilling Services Survey Report for 15-38PB1 Your Ref: AP/500292249670 Job No. AKMW2260358, Surveyed: 1 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12463.98 91.510 145.890 8847.85 8913.90 4563.04 8 3547.16 E 5955563.71 N 680390.59 E 5634.61 Tie On Point 12500.00 92.900 147.190 8846.47 8912.52 4593.06 8 3567.00 E 5955534.16 N 680411.13 E 5.283 5670.21 12527.00 93.940 148.170 8844.86 8910.91 4615.84 8 3581.41 E 5955511.73 N 680426.07 E 5.288 5696.94 12557.90 92.690 146.510 8843.07 8909.12 4641 .81 8 3598.06 E 5955486.16 N 680443.33 E 6.718 5727.51 12597.30 86.290 144.390 8843.42 8909.47 4674.24 8 3620.39 E 5955454.26 N 680466.41 E 17.111 5766.34 12627.63 82.640 144.790 8846.35 8912.40 4698.84 8 3637.88 E 5955430.08 N 680484.48 E 12.106 5796.03 - 12665.45 81.410 148.140 8851.59 8917.64 4730.05 8 3658.57 E 5955399.36 N 680505.89 E 9.355 5833.06 12700.83 81.670 149.900 8856.80 8922.85 4760.06 8 3676.58 E 5955369.79 N 680524.61 E 4.975 5867.86 12731.68 80.970 152.730 8861.46 8927.51 4786.81 8 3691 .22 E 5955343.39 N 680539.87 E 9.348 5898.29 12762.35 80.180 156.070 8866.48 8932.53 4814.09 8 3704.29 E 5955316.42 N 680553.58 E 11.047 5928.54 12801.93 79.300 161.010 8873.53 8939.58 4850.328 3718.53 E 5955280.53 N 680568.67 E 12.481 5967.40 12836.80 80.700 164.000 8879.59 8945.64 4883.07 8 3728.85 E 5955248.04 N 680579.76 E 9.350 6001.44 12875.20 80.180 168.050 8885.97 8952.02 4919.81 8 3738.00 E 5955211.53 N 680589.77 E 10.488 6038.60 12909.33 82.110 172.280 8891.23 8957.28 4953.02 8 3743.75 E 5955178.45 N 680596.30 E 13.488 6071.14 12940.40 83.520 170.170 8895.11 8961.16 4983.498 3748.46 E 5955148.11 N 680601.72 E 8.123 6100.74 12979.73 85.110 168.760 8899.01 8965.06 5021.968 3755.61 E 5955109.81 N 680609.78 E 5.392 6138.63 13036.85 92.690 166.120 8900.10 8966.15 5077.668 3768.02 E 5955054.42 N 680623.50 E 14.051 6194.36 13073.18 90.840 162.940 8898.99 8965.04 5112.658 3777.71 E 5955019.67 N 680634.00 E 10.123 6230.16 13109.25 91.370 160.480 8898.29 8964.34 5146.89 8 3789.02 E 5954985.71 N 680646.12 E 6.975 6265.98 13138.98 89.780 158.720 8897.99 8964.04 5174.758 3799.39 E 5954958.10 N 680657.13 E 7.978 6295.61 13179.55 89.250 155.720 8898.33 8964.38 5212.158 3815.09 E 5954921.08 N 680673.71 E 7.509 6336.14 13211 .72 92.600 156.250 8897.82 8963.87 5241.538 3828.18 E 5954892.01 N 680687.49 E 10.543 6368.30 13245.72 93.740 154.310 8895.93 8961.98 5272.36 8 3842.38 E 5954861.52 N 680702.41 E 6.610 6402.24 ~ 13278.77 94.100 149.380 8893.67 8959.72 5301.428 3857.93 E 5954832.83 N 680718.64 E 14.922 6435.15 13309.88 95.750 146.030 8891.00 8957.05 5327.628 3874.49 E 5954807.03 N 680735.81 E 11.968 6465.89 13339.35 96.300 143.910 8887.91 8953.96 5351.628 3891.31 E 5954783.44 N 680753.19 E 7.393 6494.75 13369.00 96.300 143.910 8884.66 8950.71 5375.43 8 3908.67 E 5954760.04 N 680771.10 E 0.000 6523.67 Projected 8urvey 6 March, 2003 - 9:50 Page 2 0'3 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for 15-38PB1 Your Ref: API 500292249670 Job No. AKMW2260358, Surveyed: 1 February, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 155.000° (True). Magnetic Declination at Surface is 26.028°(30-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13369.00ft., The Bottom Hole Displacement is 6646.27ft., in the Direction of 143.978° (True). .~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12463.98 13369.00 8913.90 8950.71 4563.04 S 5375.43 S 3547.16E 3908.67 E Tie On Point Projected Survey Survey tool program for 15-38PB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) ~. 0.00 0.00 13369.00 8950.71 MWD Magnetic(15-38) 6 March, 2003 - 9:50 Page 3 of 3 DrillQuest 3.03.02.002 Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section cc: BY ORDER OF THE COMMISSION DATED this J.7"day of January, 2003 Michael L. Bill Commissioner 'ðl-~ Sincerely, , Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least· twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). This permit to redrill . does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Enclosed is· the approved application for permit to redrill the above referenced development well. Dear Mr. Sherwood: Prudhoe Bay Unit 15-38A BP Exploration (Alaska), Inc. Permit No: 203-016 Surface Location: 1458' SNLO, 799' EWL, Sec. 22, T11N, Bottomhole Location: 2528' SNL, 5160' EWL, Sec. 27, Tl R14E, UM IN, R14E, UM !Æ ~!Æ ~ ~~!Æ AIfA~1iA. OIL AND GAS CONSERVATION COMMISSION Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~L~~E ~·.c ~J ) FRANK H. MURKOWSK/, GOVERNOR A.pproved By Form 10-401 Rev. 12-01-85 Permit Number 2CJŠ-ð/~ Conditions of Approval: r API Number 50- 029-22496-01 Samples Required 0 Yes 18 No Hydrogen Sulfide Measures Isa Yes 0 No Required Working Pressure for BOPE 0 2K Other: 'Tõ~1G'~Âe~iG1&D~C l'~ if M L. BiIt Commissioner by order of the commission Date \~?âIo3 sJbmit in \riPlicate D3K See cover letter for other requirements DYes ISI No 181 Yes 0 No 15K 0 3.5K psi for CTU hereby certify Signed Alistair that the Sherwood Sherwood, 564-4378 fore~T.,g, ~r!,,', ,,' ,'s ~~nd co~rectfo 'f11a/I~~(/~\ CT Drilling Engineer Date Ifz 3/~) my knowledge II Filing Fee II Drilling Fluid Program Contact Engineer Name/Number: Alistair 21 o Property Plat o Time vs Depth Plot II BOP Sketch o Refraction Analysis Prepared By Name/Number: Terrie Hubble, 564-4628 o Diverter Sketch o Seabed Report II Drilling Program II 20 AAC 25.050 Requirements 20. Attachments 10800' - 10830', 1 0900' - 1 0940' Slotted Liner: 11537' - 12503' 8865' - 8868', 8875' - 8878', 8897' Slotted Liner: 8916' - 8912' true vertical 8910', 8917' - 8921 8914' 8911 Perforation depth: Production Liner Slotted Liner measured 9420' 2309' 1080' 9-5/8" 7" 4-1/2" 11130' - 11230' 778 sx Class 'G' 409 sx Class 'G' Uncemented Slotted Liner 11300' 11390' 11580' 9420' 9277' - 11586' 11447' - 12527' 11670' 8308' 8219' - 8914' 8920' - 8211' Casing Structural Conductor Surface Intermediate 110' 3530' 20" 13-3/8" 260 sx Arcticset (Approx.) 1175 sx PF 'E', 375 sx Class 'G' 110' 3530' 110' 3530' measured true vertical Length 12527 feet 8911 feet 12527 feet 8911 feet Size Cemented & MD TVD Effective depth: Junk (measured) A\aska Œ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Plugs (measured) l~\N ¡ , ".;¡:.',~ G~\I II ~i ,I" ~'¡'I:::tI1 "j ~1'": } 1)010") L '-' :\" f SEC. 27, T11 2. Distance to nearest property line 113. Distance to nearest well ADL 028308,120' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 12527' MD Maximum Hole Angle 18. Casing Program Size Hole Casina 3-3/4" 3-3/16" x 2-7/8" Weiaht 6.2# /6.16# Specifications Grade L-80 Couplina ST-L Length 4480' 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14460' MD 18904' TVDss o 17. Anticipated pressure {s~O AAC 25.035 (e) (2)} 94 Maximum surface 2244 psig, At total depth (TVD) 8800' I 3300 psig Setting Depth TQO Bottom MD TVD MD TVD 9980' 8580 4460' 8904' \, Quantitv of Cement (include staae data) 113 sx Class 'G' / the best of Title COnc1l1)i~$iorfU$e.Qn'Y. 1 APprO¡aIJQ,)~ì~ , ~' II~;, J Mud Log Re uired Directional Survey Required D4K D5K D10K 0 /' At total depth 2528' SNL, 5160' EWL, x = 681259. Y = 5953797 N, R14E, UM 15-38A /' 9. APproxim~l~.I~~e. ~GÆ- Amount $200,000.00 Address P.O. Box 196612, Anchorage, Alaska Location of well at surface x = 676737, Y = 5960042 1458' SNL, 799' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval x = 678501. 3973' SNL, 2499' EWL, SEC. 22, T11 N, R14E, UM Y = 5957568 8. Well or Property Name Prudhoe Bay Unit Number Number 2S100302630-277 Type Bond (See 20 AAC 25.025) 4. 7. Unit 11 3. 99519-6612 6. Property Designation ADL 028309 Field and Pool Prudhoe Bay Field Bay Pool /' 2. Name of Operator BP Exploration (Alaska) Inc. o Drill ORe-Entry o Redrill II Deepen 20 AAC 25.005 1 b. Type of well 0 Exploratory o Service 0 Development Gas 5. Datum Elevation (OF or KB) RKB = 66.05' o Stratigraphic Test o Single Zone 10. Prudhoe / II Development Oil o Multiple Zone 1 a. Type of work ) STATE OF ALASKA \ ALAS.,-" OIL AND GAS CONSERVATION COI~...,1ISSION PERMIT TO DRILL \LJGA- I Z- 71 í)?, Reservoir Pressure Res. press. is estimated to be 3300 psi at -8800'ss (7.2 ppg emw) surface is 2244 psi. / Max. surface pressure with gas (0.12 psi/ft) to Hazards · · H28 on 15-38 has not been measured. Max recorded H28 on 0815 is 33ppm from well There are no fault crossings mapped which could cause a lost circulation event. Logging Real time MWD & Gamma Ray logs will be run over all of the open hole section 5-44 No cased hole logging is planned Directional · See attached directional plan · Magnetic and inclination surveys wi (15-38A Plan #2. Max. planned hole angle is 940 be taken every 30 ft. No gyro will be run Well Control: · BOP diagram is attached · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi · The annular preventer will be tested to 400 psi and 2500 psi /' Casing Program: /1 The production liner will be solid 2Y8~' x 3-3/16" L80, 8 , r n from TO, 14,460'md, (8904'tvdss) to 9,980'md (-7575'tvd ss). It will be cemented back to 12,100' with appro ..3 s of Class G Latex cement. The plan is to bring the cement top - 430' into the 4%" slotted liner. This will hydraulic ..isolate the sidetrack and cover a section of slotted liner, which predominantly produces gas. By using a liner top packer the option to produce the parent well is retained. Disposal: · All drilling and completion fluids and all other Class · All Class I wastes will go to Pad 3 for disposal wastes wi go to Grind & Inject. Mud Program: ~. Plan to mill the float equipment at the bottom of the 4%" slotted liner with a 1f.'6 g Flo-Pro mud system. If losses to the slotted liner become an issue, conventional LCM will be used to treat. Ther. ter an 8.6ppg Flo-Pro mud system will continue to be used to drill the formation Nordic 1 CTD rig will MIRU with 2%" coil. After milling out the float equipment of the 4%" slotted liner, -1900' of 3%" open hole will be drilled from the toe. This sidetrack will then /' be completed with solid 218" x 3-3/16" which will be cemented in place. The objective is to put the cement top at 12,100', 430' above the slotted liner shoe. This is to retain the option to produce the parent well and to preserve future sidetrack opportunities. Nordic 1 will most likely move onto 15-38 on the 31 st January 03. ,/ Phase 2, CTD Operations 1 %" service coil will drift the well with a slick nozzle BHA to TO. Any fill in the 4Y2" slotted liner will be cleaned out during this run. Next, a 3.8" mill and motor BHA will be run. This will mill the tailpipe XN nipple and again drift the 4Y2" slotted liner to TO. An injectivity test with Flo-Pro drilling fluid will then be made to assess mud losses to the slotted liner section Phase A 3%" OH through tubing sidetrack is planned for 15-38. The sidetrack, in the Ivishak Z1 B formation and target underlying 21 A reservoir sands. 1 Well preparation Summary of Operations: ) A/· 15-38 ,WI BP 15-38A CTD Sidetrack ) exit the toe of the 4%" slotted liner ~ 94-1 04 50-029-2 :gê=-óô--j . EL_~Nl in\(AlaSkM-' ." -:;::::--" CD l' y- -€.,-¡::~ W"-- DATE 09/06/94 12/19/00 02/20/01 07/14/01 03/02/02 CORRECTIONS DAV/KK ADÆRFS SIS-lsl SIS-MD RNlTP PRUDHOE BA Y UNrr WELL: 15-38 ÆRMrr No: API No: Sec. 22 T11 N COMMENTS ORIGINAL COMPLETION CONVERTED TO CANVAS FINAL DATE 03/09/02 REV BY COMMENTS RUtlh GL V UPDATE REV BY 4-1/2" LNR, ÆRFORA TION SUMMARY REF LOG: PDC-GR ON 11/15/94 ANGLE AT TOP ÆRF: 84 @ 10800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10800 - 10830 0 03/02/02 2-7/8" 4 10900 - 10940 0 03/02/02 2-7/8" 4 11130 - 11230 0 03/02/02 2-7/8" 4 11300 - 11390 0 03/02/02 3-3/8" 6 11386 - 11390 0 09/15/97 SL 32 11537 - 12503 0 09/07/94 2-7/8" 4 11580 - 11670 0 03/02/02 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 12527' .4 ~ TOP OF 4-1/2" LNR 4-1/2" LNR - SLOTTED, 0.0152 bpf. ID = 3.958" 12.6#, L-80, 7" LNR, 29#, H-95, 0.0371 bpf 12.6#, L-80, 0.0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR - SLOTTED ID = 6.184" 1--1 1-1 l-i l-i l-i 11537' 11537' 11586' 12503' 12503' I ~: ~ ~ 4-1/2" LNR, ..... 11496' 1-1 4-1/2" PORTED PIÆ (41') TOP OF 4-1/2" LNR l-i 11447' ~ ~ ~ o 18 11440' 11 7" X 4-1/2" BAKER RETRIEVABLE PKR (SET 7/09/97) 11447' l-i 7" X 4-1/2" TIW SS HORIZ PKR, ID = 4.00" 9997' 10005' l-i l-i 4-1/2" TUBING TAIL WLEG, ID = 3.805" ELMD TT LOGGED 10/15/94 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 9997' , Minimum ID = 3.725" @ 9987' 4·1/2" OTIS XN NIPPLE I I I I 9987' 9970' 1-1 l-i 4-1/2" 4-1/2" OTIS X NIP, ID = 3.812" OTIS XN NIP, ID = 3.725" ;g: I ;g: I 9935' 9914' 1-1 l-i 7" X 4-1/2" BAKER SABL-3 4-1/2" OTIS X NIP, ID = 3.812" PKR, ID = 3.89" 9-5/8" CSG, 47#, NT-80S, ID = 8.681 1-1 9420' ~ ~ 13-3/8" TOP OF 7" LNR l-i CSG, 68#, NT-80, ID = 12.415" l-i 9277' 3530' ~ ~ L I ~ 2 3 4 MD 3282 5495 7504 9224 lVD 3282 5455 7109 8185 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 MERLA DOME TG 24 MERLA S/O TG 45 MERLA DMY TG 51 MERLA DMY TG DATE 03/09/02 03/09/02 03/09/02 03/09/02 KOP= Max·-Ä"ngle-; baìÚmrvïO; Datum lV D = 4767' 94@12528ï 10839' 8800' SS - ST 2228' l-i PORT 4-1/2" CAMCO TRDP SSSV NIP, ID = 3.812" TREE = WELLHEAD= A CTüA TOR; . ,.........,."....,.....,..... KB. ELEV = Bi=:'·ËCsT;···_· _? CIW SAKERC ) 15-38 ) Safety Notes I TREE ',= WELLHEAD= ACTUA TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = Minimum ID = 3.725" @ 9987' g 4·1/2" OTIS XN NIPPLE g I LI'R Top Packer H 9955' Ij_ I TOP OF 3-3/16" LN~-i 9980' 1 Ii:::' 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 9997' 3.5" XN Nip 2.75" Iq-i 9995" 1 4-1/2" LNR, 4-1/2" LNR, DATE 09/06/94 12/19/00 02/20/01 07/14/01 03/02/02 7" LNR, 29#, H-95, 0.0371 bpf, ID = 6.184" ÆRFORA TION SUMMARY REF LOG: PDC-GR ON 11/15/94 ANGLE AT TOP ÆRF: 84 @ 10800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10800 - 10830 isolated 2-7/8" 4 10900 - 10940 isolated 2-7/8" 4 11130 - 11230 isolated 2-7/8" 4 11300 - 11390 isolated 3-3/8" 6 11386 - 11390 isolated SL 32 11537 - 12503 isolated 2-7/8" 4 11580 - 11670 isolated 13-3/8" CSG, 68#, NT-80, ID = 12.415" l-i 3530' ~ I TOP OF 7" LNR l-i 9277' r-¡ 9-5/8" CSG, 47#, NT-80S, ID = 8.681" l-i 9420' r-4 I 12.6#. L-80. 0.0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR - SLOTIED 12.6#, L-80, 0.0152 bpf, ID = 3.958" SIS-lsl SIS-MD RNITP DA V /KK REV 4767' 94 @ 12528' 10839' 8800' SS BY _? crw BAKER C 66' COMMENTS ORIGINAL COMR.ET1ON CONVERTED TO CANVAS FINAL CORRECTIONS ADÆRFS TOP OF 4-1/2" LNR 1-1 1-1 l-i l-i ) l-i proposed proposed proposed proposed proposed proposed proposed DATE 03/09/02 11447' 11537' 11537' 11586' 12527' 15-38 A Proposed CrD Sidetrack REV BY COMMENTS RLItlh GL V UPDATE ..... ~: :~ I I I I I I I I I I I I ~i' :I...·.....·.·.'i" I ,h+ .. ---I 81 :&" - 2228" l-i 4-1/2" CAMCO TRDP SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ~ 1 3282 3282 1 MERLA DOME TG 03/09/02 2 5495 5455 24 MERLA S/O TG 03/09/02 L 3 7504 7109 45 MERLA DMY TG 03/09/02 4 9224 8185 51 MERLA DMY TG 03/09/02 c o o o I ~ I I 9914' l-i 4-1/2" OTIS X NIP, ID = 3.812" g 1 9935" l-i 7" x 4-1/2" BAKER SABL-3 PKR, ID = 3.89" 81 1 I 9970' l-i 4-1/2" OTIS X NIP, ID = 3.812" 1 1 9987' l-i 4-1/2" OTIS XN NIP, ID = 3.725" 1 1 9997' l-i 4-1/2" TUBING TAIL WLEG, ID = 3.805" 1 D I 10005" l-i ELMD TI LOGGED 10/15/94 1 18 11440' 11 7"X4-1/2"BAKERRETRIEVABLE I PKR (SET 7/09/97) 8 11447' l-i 7" x 4-1/2" TIW SS HORIZ PKR, ID = 4.00" 11496" l-i 4-1/2" PORTED PIPE (41 12100' I-iTop of Liner Cement /' 12527" 1-1 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 12700" 1-13-3/16 x 2-7/8 TIW LSL X-over 1 14460" l-i 3-3/16" X 2-7/8" cmt'ed and perfed ) Safety Notes: PRUDHOI Y UNIT WELL: ÆRMIT No: I API No: ~,O-( Sec. 22 T11 N R14E, 906. BP Exploration 15-38 94-104 : )29-22496-00 , I 67 Fa. 794.28 FNL (Alas ka) ----- BP Amoco P.rent WeUpath: Tie on MD: IlIg: Kef. D.tum: V.sectlon Angle WELLPATH DETAILS '(ann 1 s..311A 500282248601 15-38 120463.88 52: 35818/188.00:00 66.05" ~~~ :::~~ ":'J~ 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/EI Reference: Well Centre: 15-38, True North v~~~~ ~:¡:~:~: š~t~ã ~~N~oÕ~)eI Measured Depth Reference: 52: 38 819/1994 00:00 66.05 Calculation Method: Minimum CurvatLJ'e SECTION DETAILS +E/·W DL.. TF.ce T.rgd ~ g~~:~ :~::: ~:::~; ~ ~~:~::g ;:::: ~:J1~ 5 12"'1.10 U.OO 101.78 i ¡~jUi ii~i¡ ¡åii 101""31.11 18.1-1 130.12 1114-311.18 11.00 111.12 12 14410.00 18.10 180.11 88-47.85 ....583.00 88-44.8e -4&015.87 :::~:~~ :::~:gg f~!~ ~~ 3547.12 0.00 0.00 ~:ii:!! ~ 1~:ii H~!:li ¡[§ :~:§ 4353.311 12.00 80.00 4373.82 12.00 270.00 5e:J4.82 5e11e.1I5 5711.81 5eo8.411 8005.12 8210.114 8537.145 17....31 7031.45 7218.150 7525.75 7803.33 ANNOTATIONS TVD +EIJI{ Shape =.~ 1~i:il ~~~ = ND AnnotaUon aa.7.115 120463.85 TIP 5~a8 12527.00 KOP 5aoU.83 12,.2.00 3 8862.03 127.2.00 . 8877'" 128.1.18 5 8884AO 13111.16 6 5801.71 13381.18 7 8802." 13831.18 8 8903.88 1.131.16 8 580..1.1oU81.16 10 a80~a 1....0.00 TO 8823.00 11056.08 TZ1B 5875.00 12811.72 TZ1A 88011.00 .13260.33_BaAD__ :EE~1~U ---------- 7600 7700 7800 7900 - .5 8000 .. Õ 8100 o "'" -8200 .c .. 0.8300 G» Q 8400 'iã .!:æ 8500 1: ~ 8600 2 8700 ... 8800 8900 rTÎÞ-¡ r-[]5ÖÞl ¡ / ft ----..-.-n·----!--·f·~ ........-..-.- ___u_1 r 15-38l~1 .~ I ··~L~_ 9000 9100 bp T AM Date: 1/16/2003 Plan: Plan #2 (15-38/P1an#2 15-38A) LEGEND 07-33 (07-33) 07-33A (07-33A) 07-33APB1 (07-33A?ß1) 07-33APB2 (07-33APB2) 15-38 (15-38) Plan#2 15-38A Plan #2 Azimuths to True North Magnetic North: 26.04° Magnetic Field Strength: 57544nT Dip Angle: 80.83° Date: 1/16/2003 Model: 6GGM2002 Created By: Bñj Potnis , , < : $ Contact lf1formalio!1: DírtJct {907} 267-€-613 Baker Hug~es I~TÊ~~ (93j}Oi6~~~:;~q·COfH iINTEQ r -3800 ª -4800 .. è5 -5000 o ~ -5200; +-5400 -. - .c .... 1: -5600· o - Z ;:;::;.. -5800 I i -6000 :s 0; en -6200~ í"--'/ i I West(-)/East(+) [200ft/in] \ \ J 1, ~ : ª : 5300 5400 5500 5600 5700 5800 5900 6000 61006200 6300 6400 6500 6~00 6700 680069007000 7100 '7200 7300 7~00 750076:0~TjOO 7800 7900 80'00 ~1'0'0' 82'0'0 ~300 ~oo 850'0 ~~OO 8700 8ioo 8JO'0 9000 9100 ' Vertical Section at 155.00° [100ft/in] - - --- ----- 1/16/2003 10:59 AM MD ft 12463.98 i 12527.00 '112542.00 12742.00 I 12841. 16 113111.16 I 13381. 16 I 13631.16 114131.16 : 14381. 16 :14460.00 111056.08 ; 12811.72 ft 8847.85 8844.86 8843.83 8862.03 8877.84 8894.40 8901.71 8902.45 8903.66 8904.14 8904.28 8823.00 8875.00 TIP KOP 3 4 5 6 7 8 9 10 TD TZ1B TZ1A Annotation 15-38A T2.2 8905.00 -6353.64 4310.97 5953792.00 681196.00 70 16 44.481 N 148 32 2.014 W 5-38A T2. 15-38A Polygon1.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 8895.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -5133.17 -4627.15 -4627.15 -4477.44 -5120.57 -6085.28 -6389.25 -6493.56 -5659.82 -4884.70 3798.49 3507.29 3507.29 3691.87 3985.85 4427.32 4549.21 4220.65 3861.13 3484.23 5955000.00 680655.00 5955499.00 680352.00 5955499.00 680352.00 5955653.00 680533.00 5955017.00 680842.00 5954063.00 681306.00 5953762.00 681435.00 5953650.00 681109.01 5954475.00 680730.00 5955241.00 680335.01 70 70 70 70 70 70 70 70 70 70 6 56.487 N 17 1.465 N 17 1.465 N 17 2.937 N 16 56.610 N 16 47.120 N 16 44.129 N 16 43.105 N 1651.307N 16 58.932 N 148 32 148 32 25.397 W 148 32 25.397 W 148 32 20.018 W 148 32 11.464 W 148 31 58.621 W 148 31 55.077 W 148 32 4.647 W 148 32 15.105 W 148 32 26.072 W 16.921 W Targets lcertainty: H "lIr~[ 1: Plan#2 15-38A 500292249601 Current Datum: 52 : 38 8/9/1994 00:00 Magnetic Data: 1/16/2003 Field Strength: 57544 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 66.05 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 15-38 12463.98 ft Mean Sea Level 26.04 deg 80.83 deg Direction deg 155.00 .,~'"-,. '''1.1 n1ln,,· I 1194.17 468.28 0.00 ft ft ft +N/-S +E/-W Northing: Easting : 5960042.10 ft 676737.10 ft Latitude: Longitude: 70 148 17 34 46.981 7.564 N W Well Position Well: Site Position: From: Map Position Uncertainty: Ground Level: 15-38 15-38 PB DS 15 TR-11-14 UNITED STATES: North Slope Northing: Easting: 0.00 ft 0.00 ft 5958837.36 ft 676296.98 ft Slot Latitude: Longitude: North Reference: Grid Convergence: Name: 70 148 38 17 34 35.236 N 21.213 W True 1.34 deg Site: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 1927 Field ) BP ) Baker Hughes INTEQ Planning Report ~;;¡~EQ 13050.00 12925.00 12950.00 12975.00 13000.00 13025.00 86.80 86.24 86.33 86.43 86.55 86.67 144.66 159.68 156.67 153.67 150.67 147.66 8891 8883.53 8885.16 8886.73 8888.26 8889.74 17 -5094.77 -4984.75 -5007.91 -5030.55 -5052.62 -5074.04 3772.41 3714.32 3723.60 3734.07 3745.72 3758.51 5955037.78 5955146.39 5955123.46 5955101.07 5955079.29 5955058.17 680628.02 680567.37 680577.18 680588.19 680600.35 680613.64 6211.72 6087.46 6112.37 6137.32 6162.24 6187.06 12.00 12.00 12.00 12.00 12.00 12.00 272.43 271.48 271.68 271.88 272.07 272.25 MWD MWD MWD MWD MWD MWD 12825.00 12841 .16 12850.00 12875.00 12900.00 84.31 86.00 86.02 86.08 86.15 168.81 169.76 168.70 165.69 162.68 8876.48 8877.84 8878.46 8880.18 8881.87 -4888.35 -4904.17 -4912.83 -4937.15 -4961.15 3689.31 3692.30 3693.95 3699.48 3706.28 5955242.17 5955226.43 5955217.81 5955193.63 5955169.80 680540.10 680543.46 680545.31 680551.41 680558.77 5989.52 6005.12 6013.67 6038.05 6062.67 12.00 12.00 12.00 12.00 12.00 29.22 29.13 271.00 271.07 271.28 MWD 5 MWD MWD MWD 12742.00 12750.00 12775.00 12800.00 12811.72 75.64 76.47 79.07 81.69 82.91 163.83 164.32 165.84 167.34 168.03 8862.03 8863.96 8869.25 8873.43 8875.00 -4809.03 -4816.49 -4840.10 -4864.07 -4875.42 3670.05 3672.18 3678.47 3684.18 3686.66 5955321.02 5955313.60 5955290.15 5955266.32 5955255.04 680518.98 680521.29 680528.13 680534.40 680537.15 5909.49 5917.16 5941.21 5965.35 5976.68 12.00 12.00 12.00 12.00 12.00 138.88 30.00 29.88 29.56 29.31 4 MWD MWD MWD TZ1A 12625.00 12650.00 12675.00 12700.00 12725.00 86.30 84.01 81.72 79.44 77.17 154.57 156.50 158.46 60.44 62.44 8843.65 8845.76 8848.87 8852.96 8858.03 -4701.34 -4724.01 -4746.92 -4770.01 -4793.22 3628.99 3639.31 3648.81 3657.46 3665.26 5955427.70 5955405.28 5955382.60 5955359.72 5955336.71 680475.40 680486.25 680496.28 680505.48 680513.82 5794.54 5819.44 5844.22 5868.81 5893.13 12.00 12.00 12.00 12.00 12.00 140.10 140.01 139.85 139.61 139.28 MWD MWD MWD MWD MWD 12527.00 12542.00 12550.00 12575.00 12600.00 93.94 93.94 93.20 90.90 88.60 148.17 148.17 148.79 150.71 152.64 8844.86 8843.83 8843.33 8842.43 8842.54 -4615.87 -4628.58 -4635.39 -4656.97 -4678.97 3581.38 3589.27 3593.44 3606.03 3617.89 5955512.03 5955499.50 5955492.80 5955471.52 5955449.80 680425.79 680433.98 680438.32 680451.40 680463.78 5696.95 5711.81 5719.74 5744.62 5769.57 5.28 0.00 12.00 12.00 12.00 43.20 0.00 140.00 140.04 140.11 KOP 3 MWD MWD MWD 85.03 91.51 91.94 92.90 93.86 131.64 145.89 146.29 147.19 148.10 5956519.47 5955564.01 5955555.01 5955534.46 5955513.70 TZ1B TIP MWD MWD MWD Survey 12463.98 12527.00 12542.00 12742.00 12841 .16 13111.16 13381.16 13631.16 13881.16 14131.16 14381.16 14460.00 91.51 93.94 93.94 75.64 86.00 87.16 89.82 89.85 89.87 89.88 89.90 89.90 145.89 148.17 148.17 163.83 169.76 137.32 169.62 139.62 169.62 139.62 169.62 160.16 8847.85 8844.86 8843.83 8862.03 8877.84 8894.40 8901.71 8902.45 8903.10 8903.66 8904.14 8904.28 .~"".""".....~ -4563.06 -4615.87 -4628.58 -4809.03 -4904.17 -5142.20 -5380.49 -5603.80 -5827.11 -6050.42 -6273.73 -6349.76 3547.12 3581.38 3589.27 3670.05 3692.30 3810.83 3929.73 4035.65 4141.56 4247.48 4353.39 4373.92 ICï 0.00 5.28 0.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 0.00 3.86 0.00 -9.15 10.45 0.43 0.99 0.01 0.01 0.01 0.01 0.00 0.00 3.62 0.00 7.83 5.98 -12.01 11.96 -12.00 12.00 -12.00 12.00 -12.00 Plan Section Information Plan: Principal: Plan #2 Similar to Lamar's Plan #2 Yes Date Composed: Version: Tied-to: 1/16/2003 6 From: Definitive Path ) BP ) Baker Hughes INTEQ Planning Report 2 ) BP ') Baker Hughes INTEQ Planning Report Survey 13075.00 86.94 141.66 8892.53 -5114.75 3787.37 5955018.16 680643.45 6236.15 12.00 272.60 MWD 13100.00 87.09 138.66 8893.84 -5133.91 3803.37 5954999.37 680659.89 6260.28 12.00 272.77 MWD 13111.16 87.16 137.32 8894.40 -5142.20 3810.83 5954991.27 680667.54 6270.94 12.00 272.92 6 13125.00 87.28 138.98 8895.07 -5152.49 3820.05 5954981 .19 680677.00 6284.17 12.00 85.85 MWD 13150.00 87.51 141.97 8896.21 -5171.75 3835.94 5954962.31 680693.34 6308.34 12.00 85.77 MWD 13175.00 87.74 144.97 8897.24 -5191.82 3850.81 5954942.60 680708.68 6332.81 12.00 85.63 MWD 13200.00 87.97 147.96 8898.18 -5212.64 3864.61 5954922.11 680722.96 6357.51 12.00 85.51 MWD 13225.00 88.22 150.95 8899.01 -5234.16 3877.31 5954900.90 680736.16 6382.38 12.00 85.40 MWD 13250.00 88.47 153.94 8899.73 -5256.31 3888.86 5954879.03 680748.24 6407.34 12.00 85.30 MWD 13260.33 88.57 155.18 8900.00 -5265.64 3893.30 5954869.81 680752.89 6417.67 12.00 85.21 BSAD 13275.00 88.72 156.93 8900.35 -5279.04 3899.25 5954856.55 680759.15 6432.33 12.00 85.18 MWD 13300.00 88.97 159.92 8900.85 -5302.28 3908.44 5954833.53 680768.89 6457.28 12.00 85.14 MWD 13325.00 89.23 162.91 8901.24 -5325.97 3916.41 5954810.04 680777.41 6482.12 12.00 85.08 MWD 13350.00 89.49 165.90 8901.52 -5350.05 3923.13 5954786.13 680784.69 6506.78 12.00 85.03 MWD 13375.00 89.76 168.89 8901.68 -5374.44 3928.58 5954761.87 680790.72 6531.19 12.00 85.00 MWD 13381.16 89.82 169.62 8901.71 -5380.49 3929.73 5954755.85 680792.01 6537.16 12.00 84.98 7 13400.00 89.82 167.36 8901.76 -5398.96 3933.49 5954737.48 680796.20 6555.48 12.00 270.00 MWD 13425.00 89.82 164.36 8901.84 -5423.20 3939.59 5954713.39 680802.87 6580.03 12.00 270.01 MWD 13450.00 89.82 161.36 8901.92 -5447.08 3946.96 5954689.69 680810.80 6604.79 12.00 270.02 MWD 13475.00 89.82 158.36 8902.00 -5470.55 3955.56 5954666.43 680819.95 6629.70 12.00 270.03 MWD 13500.00 89.83 155.36 8902.07 -5493.54 3965.38 5954643.68 680830.31 6654.68 12.00 270.03 MWD 13525.00 89.83 152.36 8902.15 -5515.98 3976.40 5954621.51 680841.84 6679.67 12.00 270.04 MWD 13550.00 89.83 149.36 8902.22 -5537.81 3988.57 5954599.97 680854.52 6704.60 12.00 270.05 MWD 13575.00 89.84 146.36 8902.29 -5558.98 4001.86 5954579.12 680868.31 6729.41 12.00 270.06 MWD 13600.00 89.84 143.36 8902.37 -5579.42 4016.25 5954559.02 680883.18 6754.01 12.00 270.07 MWD 13625.00 89.84 140.36 8902.43 -5599.08 4031.69 5954539.73 680899.07 6778.36 12.00 270.08 MWD 13631.16 89.85 139.62 8902.45 -5603.80 4035.65 5954535.11 680903.14 6784.31 12.00 270.09 8 13650.00 89.85 141.89 8902.50 -5618.39 4047.56 5954520.80 680915.40 6802.57 12.00 90.00 MWD 13675.00 89.85 144.89 8902.57 -5638.46 4062.4 7 5954501.10 680930.77 6827.05 12.00 89.99 MWD 13700.00 89.85 147.89 8902.64 -5659.27 4076.31 5954480.61 680945.10 6851.77 12.00 89.99 MWD 13725.00 89.85 150.89 8902.70 -5680.79 4089.04 5954459.41 680958.33 6876.64 12.00 89.98 MWD 13750.00 89.85 153.89 8902.77 -5702.94 4100.63 5954437.54 680970.43 6901.62 12.00 89.97 MWD 13775.00 89.85 156.89 8902.83 -5725.66 4111.04 5954415.06 680981.37 6926.61 12.00 89.96 MWD 13800.00 89.85 159.89 8902.90 -5748.90 4120.25 5954392.05 680991.12 6951.57 12.00 89.95 MWD 13825.00 89.86 162.89 8902.96 -5772.59 4128.23 5954368.55 680999.66 6976.41 12.00 89.95 MWD 13850.00 89.86 165.89 8903.02 -5796.67 4134.95 5954344.65 681006.95 7001.07 12.00 89.94 MWD 13875.00 89.86 168.89 8903.08 -5821.06 4140.41 5954320.39 681012.98 7025.49 12.00 89.93 MWD 13881.16 89.87 169.62 8903.10 -5827.11 4141.56 5954314.37 681014.27 7031.45 12.00 89.92 MWD 13900.00 89.87 167.36 8903.14 -5845.57 4145.32 5954296.00 681018.46 7049.77 12.00 270.00 MWD 13925.00 89.87 164.36 8903.20 -5869.81 4151.42 5954271.91 681025.13 7074.32 12.00 270.01 MWD 13950.00 89.87 161.36 8903.26 -5893.70 4158.79 5954248.21 681033.06 7099.09 12.00 270.01 MWD 13975.00 89.87 158.36 8903.32 -5917.17 4167.40 5954224.95 681042.21 7123.99 12.00 270.02 MWD 14000.00 89.87 155.36 8903.37 -5940.15 4177.22 5954202.20 681052.57 7148.98 12.00 270.03 MWD 14025.00 89.87 152.36 8903.43 -5962.60 4188.23 5954180.02 681064.11 7173.97 12.00 270.03 MWD 14050.00 89.87 149.36 8903.48 -5984.43 4200.40 5954158.48 681076.79 7198.90 12.00 270.04 MWD 14075.00 89.88 146.36 8903.54 -6005.60 4213.70 5954137.64 681090.58 7223.70 12.00 270.05 MWD 14100.00 89.88 143.36 8903.59 -6026.04 4228.08 5954117.54 681105.44 7248.31 12.00 270.05 MWD 14125.00 89.88 140.36 8903.64 -6045.70 4243.52 5954098.25 681121.33 7272.65 12.00 270.06 MWD 14131.16 89.88 139.62 8903.66 -6050.42 4247.48 5954093.63 681125.40 7278.60 12.00 270.07 9 14150.00 89.88 141.89 8903.69 -6065.01 4259.40 5954079.32 681137.66 7296.86 12.00 90.00 MWD 14175.00 89.88 144.89 8903.74 -6085.07 4274.31 5954059.61 681153.03 7321.35 12.00 90.00 MWD 14200.00 89.88 147.89 8903.80 -6105.89 4288.14 5954039.13 681167.36 7346.06 12.00 89.99 MWD 14225.00 89.89 150.89 8903.85 -6127.40 4300.87 5954017.92 681180.59 7370.94 12.00 89.98 MWD ') BP ) Baker Hughes INTEQ Planning Report Survey 14250.00 89.89 153.89 8903.89 -6149.55 4312.46 5953996.05 681192.69 7395.91 12.00 89.98 MWD 14275.00 89.89 156.89 8903.94 -6172.28 4322.87 5953973.58 681203.63 7420.91 12.00 89.97 MWD 14300.00 89.89 159.89 8903.99 -6195.52 4332.08 5953950.56 681213.39 7445.86 12.00 89.97 MWD 14325.00 89.89 162.89 8904.04 -6219.21 4340.06 5953927.07 681221.92 7470.70 12.00 89.96 MWD 14350.00 89.90 165.89 8904.08 -6243.28 4346.79 5953903.16 681229.21 7495.37 12.00 89.95 MWD 14375.00 89.90 168.89 8904.13 -6267.67 4352.25 5953878.91 681235.24 7519.78 12.00 89.95 MWD 14381.16 89.90 169.62 8904.14 -6273.73 4353.39 5953872.88 681236.53 7525.75 12.00 89.94 10 14400.00 89.90 167.36 8904.17 -6292.19 4357.15 5953854.52 681240.72 7544.07 12.00 270.00 MWD 14425.00 89.90 164.36 8904.22 -6316.43 4363.26 5953830.43 681247.40 7568.62 12.00 270.00 MWD 14450.00 89.90 161.36 8904.26 -6340.31 4370.62 5953806.72 681255.32 7593.38 12.00 270.01 MWD 14460.00 89.90 160.16 8904.28 -6349.76 4373.92 5953797.36 681258.84 7603.33 12.00 270.01 TD production christmas tree r ~L Manual over Hydraulic 7-1/16" ID, 5000 psi Ram Type Dual Full Gate BOPE XO Spool TOT~ 2 3/8" x 3 1/2" VBRs ~ " 23/8" Combi Pipe/Slip 2 flanged gate valves Inner Annulus Outer Annulus r / i (. ," :''') I!' , I ' . working pressure Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR TOT '-- I t=é ~ Kill line check valve I -\NÒ-: " Combi Pipe/Sli~ ....... /'. Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipf / manifold ./ I Blind/Shear /' 8tis 7" WLA Quick onnect - 7-1/16" 10,5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I r , I I (0) I I as necessary \ / I I ® I I ® I I THA I J Tubing - @-.J1 Spool ~ - I ~©1-~ Methanol Injection ~ Mð '- 7" Riser aU ---- o~ Stuffing Box -- CT Injector Head (Pack-Off), 10,000 psi Working Pressure t J' Nordic CTD BOP Detail ) ) Alistair Sherwood Coil Tubinn Dri!ling Ennineer Greater Prudhoe nay OP Exploratìon (AI~)$ka) HOO E. Benson Blvd. Anchorage +(907) [5ß4 43'78 +(90"1) 440 830 Regards The surface location coordinates on the completion schematic is in error. The coordinates on Form 10-403 are correct. From the opposite lines as defined in the completion schematic, the numbers should have read, 5201 FEL and 794 FNL to match the true surface coordinates. When the completion schematic is updated after the sidetrack, we will make sure this error is corrected. Winton 15-38 Surface Location Co-ordinates. ) Subject: 15-38 Surface Location Co-ordinates. Date: Mon, 27 Jan 2003 14:09:31 -0600 From: "Sherwood, Alistair" <SherwooA@BP.com> To: "Winton Aubert (E_mail)..<winton_aubert@admin.state.ak.us> ) Alista.ir Sherwood Coil Tubinø Drilling Engìnee Greater Prudhoe Bay BP Exploration (Alaska) 900 E. Benson Blvd, AnchorarJe. -(007) 564 43i'8 '(907) 440 a30 Regards The reason we have found ourselves in this situation is because of the delays in preparing well annuli pressure issues with need to be resolved before rig up, hence the deferral 15-48 Over the weekend, Nordic 1 CTD rig tore up 15-158. The liner has now been run & cemented in place, and I anticipate the rig being ready to move to 15-38 some time tomorrow. I hate to ask, but is there any way you could push the 10-401, permit to drill for 15-38A through your system before the end of business, tomorrow, Tue 28th. We currently have 5-38A Winton 0-401 Subject: 15-38A 10-401 Permit To Drill Date: Mon, 27 Jan 2003 13:31 :01 -0600 From: "Sherwood, Alistair" <SherwooA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Permit To Drill ) ) P054994 12/19/2002 P054994 l~j !1 " ø-, f" ~~~~f 3 í DATE CHECK NO. DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET ,_ ¡ Ä !\J ~--- -f ~ß' 'j U .J /{ ?íi 1 ijrH8~ OU &4~~îg~;;~ :~~::ìS8iOn -' 12/19/2002 INV# CK121702C PERMIT TO DRILL FEE \ S~ 38A- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY: '.. - --- ----. ,.._'. cu_-. "."-.-'"."- ..-. .. '.- . -." -. . ~ ~ ·ij--~F-,.-~; ::::--:-~-'-:: .-::/:::;:= :<:-/", : ,'-':;":-.>-:;:-" - - '- ~--:.-:.:. - . .~ 8,.iP.~4¡Pc!t~;i~t .~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 '.' 56-389. .. 412 ..... - - - - N()·r;pc.Y~:rO:S.49:·8.;·4 . CôNSÖÙDÅTEÔ.6òMMERClALAC?'!2~r . . .. ~-,- . >~.:.: -". .. . . .. . , h_ . ·..·····;':AMOUNT·< . '. .' - -- ~ .-::.:..;:.:;:.; - -. .-. :-:: :-::~:. . - : -.: ':.-:-..- ~ - - -' - -:.- .... De8êmb$t~i9,~Ó()2," __n TO THE ORDER OF: . ..' . _ '"_:, : -.' <.:::.':." ~-_: _.:::.-::' . :.._:.._ .: ,-;" . .. . ..:~.:.: .~:-:;- _.::.:-.:.< _ ...-:._ .->.:.'.~.; ._:...·.0 _. -_.:-.-.' .};:.- >-:. ALASKA OIL & GAS CqNSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100.'·<.\.;":: . . ANCHORAGE,AK.~950t . .*f~*~~~~~~**~.~$10Ò.ÒO*~* .'. 2 . . . ..:.:-.."' NQTW~~.~R.~.~~~.~O~VfL '..:..,. -'.i " ..' '.~ ,.~:.~::~~ ~~:.:. :':" ::. .~\: :::~:~:::·=.S~:" ,..::~~:~~}.~.:;:~~~}:~ . ..~ .........._"'._. .._. "'M" ..... ......... .~:.. .. :;-.."... :.\. ~.... :~.. .:......, }/\~:.:~~~ .~:\: ~.:~~;\~:;;/i.i:~;:t;:i:.:~·;::~~;)~:~~~.~ ".-~. . ;.:.:. H ..... :-·-::...:;::7:.:. _n ..< - . Rev: 07/10/02 C\jody\templates DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. PILOT (PH) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from. records, data and logs acquired for well (name on permit). HOLE (If API number last two (2) digits are between 60-69) The permit is existing well " Permit No, API No. . Production should continue to be reported as a function' of the original API number stated above. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL for a new well bore "CLUE" segment of PTD# WELL NAME TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ) ) { _ Serv _ Well bore seg / / ~ S'ð ON/OFF SHORE ..Q1Ù Redrll ~ Re-Enter UNIT# DevX ~7~ [{ ,to f PI 2 7- t.f<{- p~ [' ( PROGRAM:Exp GEOL AREA Ç'N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N \tiN ~y ¡U.A. YN Y N -y N -Y N Al/A- kì N i~"~ N (.(CD , , N tt2.cf~ . ~"N wA- , ",. N ;41 "''I- tJ1 IN ~ fJ2sp ~N Y~ .y N·/IJ.//t;- y<NJ ~Y, /U Y N N f>8u /.c!)'-.??A I-t-;J,¡/ WELL PERMIT CHECKLIST COMPANY FIELD & POOL C, t7-' 6/ f r) ADMINISTRATION 1. Permit fee attached. . . . . . . 2. Lease number appropriate. . . 3. Unique well name and number. . . 4. Well located in a defined pool.. . . . . . . . . . .. . 5. W ell located proper distance from drilling unit boundary. 6. W ell located proper distance from other wells.. . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . 8. If deviated, is we II bore plat included.. . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . , 10. Operator has appropriate bond in force.. . . . . . . . 11. Permit can be issued without conservation order. . . . 12. Permit can be issued without administrative approval.. . . 13. Well located w!in area & strata authorized by injection order # 14. All wells w/in X mile area of review identified. . WELL NAME INIT CLASS O~.Jv ßfJX DATE þYq3 APPR I{r: ENGINEERING APPR DATE v.tA- 111.7/o~ '(Service Well Only) GEOLOGY APPR DATE ø~. ~~ (Exploratory Only) Rev: 10/15/02 15. Conductor string provided. . . " . . . . . . 16. Surface casing protects all known USDWs.. .., 17. CMT vol adequate to circulate on conductor & surf csg. 18. CMT vol adequate to tie-in long string to surf csg. . . . 19. CMT will cover all known productive horizons. . . . . . 20. Casing designs adequate for C, T, B& permafrost. . . 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. 23. Adequate wellbore separation proposed.. .." . . . . 24. If diverter required, does "it meet regulations. .. . . . 25. Drilling fluid program schematic & equip list adequate. 26. BOPEs, do they meet regulation. . . . . . . . . . . 27. BOPE press rating appropriate; test to 3500 psig. ~8. Choke manifold complies w/API RP-53 (May 84). 29. Work will occur without operation shutdown. . . . 30. Is presence of H2S gas probable.. . . . . . . . . 31. Mechanical condition of wells within AOR verified. Only) Only) (Service Wel (Service Wel ¡;¡ 32. Permit can be issued w/o hydrogen sulfide measures. 33. Data presented on potential overpressure zones. 34. Seismic analysis of shallow gas zones. . . . . . 35. Seabed condition survey (itoff-shore). . . . . . . 36. Contact namelphone for weekly progress reports. Comments/Instructions: RESERVOIR ENGINEERING ule ENGINEER COMMISSIONER: JDH JBR eOT DTS ~,í/'¿7/0 J MJW MLB ð/ /.:z. V03 PETROLEUM ENGINEERING: TEM WGA /' GEOLOGY: RP¡iÞ:::; SFD G:\geology\permits\checklist.doc ') ) We History File APPENDIX nformation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. " To improve the readability of the Well History file and to sim,plify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information ~~"\)"f\.~ l. THIS fILE SUPERCEDES ALL PREVIOUS LDWG fILES fOR WELL l5-38A PBl, AND INCLUDES ALL PROPERLY DEPTH SHIfTED MERGED CURVES Page 1 ~~~\~~~\a o ('~ f~ 1..1 \", ~~nct~Ot~~~·If.:. ,;C;1~!T:~f)~¡On ~ REHARKS i ~r::~:~ ;thii'r:.~ u ;:~ (; ~'\i' l~:5 ]'~ [: (\': " J" \-f\Th~"tI 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE 4.130 3.750 CASING SIZE (IN 4.500 4.500 DRILLERS DEPTH (fT 12527.0 12527.0 IN # WELL CASING RECORD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: [SL: FEL: FWL: ELEVATION (FT FROM MSL KELLY BUSHING DERRICK FLOOR GROUND LEVEL: o 799 66 22 llN 14E 1458 05 00 00 JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS MWD RUN .1 MW3002000000 S. LATZ EGBEJIMBA/SE MWD RUN 2 MW3002000000 S. LATZ EGBEJIMBA/SE Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS if WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE # JOB DATA 15-38A PB1 5002922496 SP Explora Sperry Sun 09-0CT-03 '7 t Redo o ion Alaska Inc Physical Tape Header Service name Date....... . Origin. '" ... . Tape Name........ Continuation Number Previous Tape Name Comments. . . EOF .LISTPE .03/10/09 .STS . UNKNOWN .01 . UNKNOWN .STS LIS Writing Library Scientific 'I'echni.cal Services Reel Header Service na.me Date....... . Origin. . . . . . Reel Name... Continuation Previous Rc,"el Comments . . . . . Number Name LISTPE 03/10/09 STS UNKNOWN 01 UNKNOWN S'I'S LIS Writing Library Scient i fic Technical Services $Revision: 3 $ Lis Lib $Revision: 4 Thu Oct 09 10:39:02 $ 2003 Sperry-Sun Drilling Services LIS Scan Utility ') 15-38apb1redo.txt ') <Yâ3-0((¡J / ~'-fO BASELINE DE PTH 11245.0 11253.0 11261. 5 11263.5 11272.5 11274.0 11279.0 11284.5 11292.0 11296.5 12540.5 1:2569.5 12574.5 12584.5 12626.5 GR 11240 11248 11256 11258 11266 11267 11274 11279 11285 11291 12540 12569 12572 12583 12625 o o o o 5 5 5 o 5 5 o o 5 o o paqe ,., # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shi Hed DEPTH INCREMENT: # FILE SUMMARY PBU '1'OOL CODE GR ROP $ START 11245 12557 DEPTH o o STOP DEPTH 13343.5 13371. 5 and 1 clipped curves; all bit runs merged 5000 ) ) 15-38apb1redo.txt 2. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 3. ALL VE,RTICAI., DEPTHS ARE SUB SEA TRUE VERTICAL DEPTHS (SSTVD) . 4. MWD RUNS 100, 200 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MULLER TUBE DETECTORS. 5. MWD DATA ARE DEPTH SHIFTED TO THE PDC GAMMA RAY LOG OF 02-10-03 (SWS MGR) TO LAST COMMON DEPTH POINT OF 12731'MD, 8861'SSTVD. MWD DATA IS TIED TO LOG DATA OF 15-38 PARENT WELLBORE FROM 11240-11301.5'MD. DIGI'I'AL DATA AND LOG CURVES ARE SHIFTED, BUT LOG HEADER AND THESE REMARKS REFERENCE ORIGINAL DRILLER'S DEPTHS. WELL 15-38A KICKS OFF FROM THIS WELL AT 12731'MD, 8861'SSTVD. 6. MWD RUNS 100, 200 REPRESENT WELL 15-38A PBl WITH API # 50-029-22496-70. 'I'HIS WELL REACHED A TO'I'AL DEPTH ('I'D) OF 13369' MD, 8885' TVD. SROP = SMOOTHED RATE OF PENE'I'RATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED l' " File Heade Service name.............STSL1B.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/10/09 ~1aximum Physical Record.. 65535 File Type......... 1,0 Previous File Name STSL1B.000 File Trailer Service name. ..S'1'SLI8.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/10/09 Maximum Physical Record..65535 File Type................ LO Next File Name...... .... .S'1'8LI8.002 Physical EOF t'ile Header Service name............. 8TSLI8. 002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....03/10/09 Maximum Physical Record. .65535 File Type......... LO Previous File Name 8T8LI8.001 Comment Record Page 3 First Reading For Entire File Last Reading nor Entire File Name DEPT ROP GR MWD MWD Service Unit FT FT/H API Mi 11245 0.92 28.7 11245 13371.5 Max 13371. 5 1377.18 210.34 Mean 1230tJ.3 86. tJ202 106.063 Nsam 4254 1630 1756 First Reading 11245 12557 11245 Last Reading 13371. 5 13371. 5 13343.5 Name Service DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Nsam Rep Code 1 68 1 68 1 68 Offset o 4 8 Channel 1 2 3 Order If Data Format Specification Record Data Record. Type............. Data Specification 810ck Type Logging Direction...... Optical log depth units Data Reference Point. Frame Spacing........ Max frames per record Absent value....... Depth Units........ Datum Specification .. .. .. .. .. Block . .. .. .. .. .sub-type o o o Down Feet Undefined 60 .lIN Undefined -999.25 # REMARKS # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ MERGED MAIN $ BIT HUN NO 1 2 PASS MERGE TOP 11240.0 13218.0 MERGE BASE 13218.0 13369.0 12636 12639 12651 12663 12688 12700 12703 12728 13371 $ 5 o 5 o o 5 5 5 5 12633 12635 12649 12662 12686 12699 12703 12726 13369 o 5 5 o o 5 5 o o ) 15-38apb1redo.txt ') Name Service Order Units Size Nsam Rep Code Offset Channel Page 4 # Data Format Specification Record Data Record Type............. Data Specification Block Type Logging Direction...... Optical log depth units Data Reference Point. Frame Spacing........ Max frames per record Absent value....... Depth Units........ Datum Specification .. .. ...... Block .. ... .. .. .. .. .. .. sub-type o o Down Feet Undefined 60 .1IN Undefined -999.25 o # REMARKS $ !i TOOL STANDOFF EWR FREQUENCY NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN HZ IN # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G MUD VISCOSITY (S) MUD PH: MUD CHLORIDES (PPM FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.70 65.0 9.0 23000 8.0 000 000 000 000 167 o o o o .# BOREHOLE AND CASING DA'rA OPEN HOLE BIT SIZE (IN DRILLER'S CASING DEPTH FT 4.130 12527.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL 78012 II HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT BIT ROTATING SPEED (RPM HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 80 92 2 7 NUMBER 01-FEB-03 Insite 4.3 Memory 13218.0 Curves and log header BIT RUN NUMBER: 1 DEPTH INCREMENT: 500 # FILE SUMMARY VENDOR TOOL CODE GR ROP $ # LOG START 11240 12556 DEPTH o 5 STOP DEPTH 13191. 0 13218.0 FILE HEADER FII,E NUMBER RAW MWD 2 ) 15-38apb1redo.txt data for each bit run in separate files ') TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA 93.7 96.3 TOOL NUMBER 82758 Page 5 If LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT BIT ROTATING SPEED (RPM HOLE INCLINATION (DEG MINIMUM ANGLE MA.,,\IMUM ANGLE Insite 4.3 Memory 13369.0 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 13191.5 13218.5 STOP DEPTH 13341.0 13369.0 02-FEB-03 5000 leader 2 each bit ["un in separate files Comment Record FILE HEADER FILE NUMBER RAW MWD 3 data for File Header Service name....... Service Sub Level Name Version Number........ Date of Generation..... Maximum Physical Record File Type......... Previous File Name Physical File Trailer Service name........ Service Sub Level Name Version Number........ Date of Generation..... Maximum Physical Record File Type..... Next File Name EOF STSLIB.002 1. 0.0 03/10/09 65535 LO STSLIB.003 STSLIB.003 1. 0.0 03/10/09 65535 LO STSLIB.002 First Reading For Entire File Last Reading For Entire File 11240 13218 Name DEPT ROP GR Service Unit FT MWD010 FT/H MWD010 API Min 11240 0.92 28.7 Max 13218 1377 .18 210.34 Mean 12229 92.8033 102.394 Nsam 3957 1324 1452 First Reading 11240 12556.5 11240 Last Reading 13218 13218 13191 DEPT ROP GR MWD010 MWDOlO FT FT/H API 1 1 1 ) 68 68 68 15-38apb1redo o 4 8 txt 1 2 3 ) Physical EOF Tape Trailer Service name Date LISTPE 03/10/09 Page 6 file Trailer Service name..... Service Sub Level Version Number... Date of Generation.. ... Maximum Physical Record file Type..... Next File Name Name STSLI8.003 1. 0.0 03/10/09 65535 LO STSLI8.004 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13191.5 13369 13280.3 356 13191.5 13369 ROP MWD020 FT/H 2.35 232.3 61.0449 302 13218.5 13369 GR MWD020 API 58.26 192.21 124.132 300 13191. 5 13341 First Reading For Entire File 13191. 5 Last Reading For Entire File 13369 # Data Format Specification Record Data Record Type............. Data Specification Block Type Logging Direction............ Optical log depth units...... Data Reference Point......... Frame Spacing.... ............ Max frames per record........ Absent value................. Depth Units.................... Datum Specification Block sub-type o o Down Feet Undefined 60 .lIN Undefined -999.25 o II NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN 11 TOOL STANDOFF (IN EWR FREQUENCY (HZ II REMARKS .$ BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G MUD VISCOSITY (S) MUD PH: MUD CHLORIDES (PPM fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPEI~TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE .AT MT: MUD CAKE AT MT: 000 000 000 000 Flo Pro 8.90 65.0 8.5 25000 7.6 169 o o o o OPEN HOLE DRIl,LER'S 8IT SIZE (IN CASING DEPTH F'T ) 15-38apb1redo.txt 3.750 12527.0 ) Page 7 End Of LIS File Physical EOF Reel Trai Service Date.. . Origin. Reel Name Continuation Number Next Reel Name Comments Physical EOF LISTPE 03/10/09 STS UNKNOWN 01 UNKNOWN S1'S I,IS Wd ting .L:[ br.'ary Scientific Technical Services er name Origin Tape Name __ Continuation Number Next Tape Name Comments STS UNKNOWN 01 UNKNOWN STS LIS Writing Library Scientific Technical Services ) 15-38apblredo.txt ') ~~b~ ALL DEPTHS NOTED. : :;t:"~~:?l 2 ARE MEASURED DEPTHS THIS FILE SUPERCEDES ALL PREVIOUS LDWG FILES WELL 15-38A, AND INCLUDES ALL PROPERLY DEPTH SHIFTED MERGED CURVES MD UNLESS OTHERWISE (ì ..I '''''"',j; ~r.¡ .u'""J:~ ,~~~"~:({,,:.~~ 'v # REMARKS 1ST STRING 2ND STRING 3RD STRING PRODUCTION 1 STRING OPEN HOLE BIT SIZE 4.130 3.750 3.750 CASING SIZE (IN 4.500 4.500 4.500 DRILLERS DEPTH (FT 12527.0 12527.0 12527.0 FOR IN # WELL CASING RECORD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL KELLY BUSHING DERRICK FLOOR GROUND LEVEL: o 799 66 22 llN 14E 1458 05 00 00 JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS MWD RUN 1 MW3002000000 S. LATZ EGBEJIMBA/SE MWD RUN 3 MW3002000000 S. LATZ EGBEJIMBA/SE MWD RUN 4 MW3002000000 S. LATZ SARBER / WHI Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE # JOB DATA 15-38A redo 500292249601 BP Exploration Sperry Sun 07-0CT-03 Alaska Inc Physical EOF Tape Header Service name Date....... . Origin...... Tape Name........ Continuation Number Previous Tape Name Comments. LISTPE 03/10/07 STS UNKNOWN 01 UNKNOWN STS LIS Writing Library Scientific Technical Services Reel Header Service name Date....... . Origin. . . . . . Reel Name........ Continuation Number Previous Reel Name Comments LISTPE 03/10/07 STS UNKNOWN 01 UNKNOWN STS LIS Writing Library Scientific Technical Services ") Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Oct 07 15:35:39 2003 ) &ð3-oftp IJ~3C{ ) ) 3 ALL VERTICAL DEPTHS ARE SUB SEA TRUE VERTICAL DEPTHS SSTVD) . 4 MWD RUNS 100, 300 - 400 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MULLER TUBE DETECTORS. 5. MWD RUN 300 REAL TIME GAMMA RAY USED FROM 12731' - 13 7 8 5' MD. 6. MWD DATA ARE DEPTH SHIFTED TO THE PDC GAMMA RAY LOG OF 02-10-03 (SWS MGR) . MWD DATA IS TIED IN TO LOG DATA OF 15-38 PARENT WELLBORE FROM 11240-11301.5 DIGITAL AND LOG DATA MERGED RUNS ARE SHIFTED, BUT LOG HEADER AND REMARKS DA REFERENCE ORIGINAL DRILLER'S DEPTHS. THIS WELL KICKS OFF FROM 15-38APB1 AT 12731'MD, 8861'SSTVD. 7. MWD RUNS 100, 300 - 400 REPRESENT WELL 15-38A WITH API # 50-029-22496-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 14142' MD, 8870' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/07 Maximum Physical Record. .65535 File Type.. ..... ........ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11245.5 14114.0 ROP 12557.5 14141. 5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 11245.5 11240.0 11254.0 11248.5 11261.5 11256.0 11271. 0 11265.0 11276.0 11270.5 11286.5 11281.0 11288.0 11282.0 11292.5 11286.0 12540.0 12540.0 12575.0 12572.5 12577.0 12574.5 12584.0 12582.5 12595.5 12596.5 12610.0 12609.0 12618.0 12615.5 12636.0 12632.0 12648.5 12644.0 12651. 0 12651. 0 12654.5 12655.5 12663.5 12662.0 12687 12700 12710 12713 12734 12740 12759 12791 12807 12838 12846 12850 12860 12864 12877 13024 13046 13053 13073 13080 13087 13096 13105 13121 13125 13149 13156 13162 13193 13199 13202 13203 13207 13210 13212 13220 13224 13227 13229 13244 13246 13264 13273 13280 13293 13308 13346 13350 13359 13375 13434 13470 13503 13513 13561 13563 13568 13570 13573 13578 13595 13603 13620 13627 13645 13651 13660 13665 13667 13683 13701 13712 13720 13736 13739 13759 o 5 o o o o o 5 5 5 o 5 5 o o o 5 o 5 o 5 5 5 o 5 5 5 5 5 o o 5 5 o o 5 5 o o o 5 5 o o o 5 5 5 5 o 5 5 o o o 5 5 o o 5 5 o 5 5 o 5 o 5 5 5 o o o 5 o o 12685 12699 12711 12717 12737 12746 12762 12793 12809 12845 12852 12856 12866 12870 12882 13025 13046 13053 13076 13081 13088 13096 13107 13120 13124 13150 13157 13162 13193 13198 13202 13204 13208 13210 13213 13220 13224 13226 13228 13243 13244 13262 13271 13278 13290 13307 13349 13355 13365 13382 13439 13473 13508 13519 13565 13567 13571 13573 13579 13583 13597 13603 13621 13 62 9 13 64 6 13654 13663 13668 13670 13 68 6 13706 13717 13723 13740 13743 13 762 ) .5 .5 .0 .5 .5 .5 .0 .5 .5 .5 .0 .5 .5 .0 .5 .5 .5 .0 .5 .5 .5 .0 .0 .0 .5 .0 .0 .5 .0 .5 .5 .5 .5 .0 .5 .0 .0 .5 .5 .0 .5 .5 .5 .5 .5 .5 .0 .0 .0 .5 .0 .5 .5 .5 .0 .5 .5 .5 .0 .5 .5 .0 .5 .5 .5 .5 .0 .5 .0 .5 .5 .5 .5 .5 .0 .5 ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11245.5 14141.5 12693.5 5793 11245.5 14141.5 ROP MWD FT/H 0 1405.73 69.2218 3169 12557.5 14141.5 GR MWD API 28.7 243.44 79.5361 3266 11245.5 14114 First Reading For Entire File 11245.5 Last Reading For Entire File 14141.5 File Trailer # Data Format Specification Record Data Record Type.... ......... Data Specification Block Type Logging Direction...... Optical log depth units Data Reference Point. Frame Spacing........ Max frames per record Absent value....... Depth Units........ Datum Specification . . . . . Block . . . . . sub-type o o o Down Feet Undefined 60 .1IN Undefined -999.25 # REMARKS # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ MERGED MAIN PASS $ BIT RUN NO 1 3 4 MERGE TOP 11240.0 12731.0 13808.0 MERGE BASE 12731. 0 13808.0 14141. 5 13 763 13783 13809 13812 13815 13817 13833 13846 13866 13871 13890 13899 13901 13904 13928 13934 13942 13961 13981 13984 14001 14004 14005 14010 14017 14049 14052 14066 14071 14073 14076 14088 14141 $ 5 o 5 5 o o 5 5 o 5 o 5 5 o o o 5 o 5 5 o o o o 5 5 5 5 5 5 5 5 5 13767 13788 13812 13816 13818 13820 13838 13853 13872 13876 13893 13904 13906 13909 13932 13939 13946 13960 13983 13987 14002 14006 14007 14011 14019 14049 14053 14070 14074 14077 14078 14088 14141 5 5 5 5 5 5 5 o o o 5 5 o 5 o 5 5 5 o o o o 5 5 5 5 5 o 5 o 5 5 5 ) ') # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G MUD VISCOSITY (S) MUD PH: MUD CHLORIDES (PPM) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: 000 000 000 000 Flo Pro 8.70 65.0 9.0 23000 8.0 167 o o o o # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN DRILLER'S CASING DEPTH FT 4.130 12527.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL 78012 NUMBER # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT BIT ROTATING SPEED (RPM HOLE INCLINATION (DEG MINIMUM ANGLE MAXIMUM ANGLE 80.2 92.7 01-FEB-03 Insite 4.3 Memory 12731. 0 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 1 DEPTH INCREMENT 5000 # FILE SUMMARY VENDOR TOOL GR ROP $ START 11240 12556 DEPTH o 5 STOP DEPTH 12704.0 12731. 0 CODE for each bit run in separate files ) Service name. . . . . .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .03/10/07 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name........ ...3T3LIB.002 Physical EOF File Header Service name.......... ...ST3LIB.002 3ervice 3ub Level Name... Version Number. .... ..... .1.0.0 Date of Generation...... .03/10/07 Maximum Physical Record. .65535 File Type......... LO Previous File Name 3T3LIB.001 ) Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12704.5 13781. 0 ROP 12731. 5 13808.0 $ # LOG HEADER DATA DATE LOGGED: 06-FEB-03 SOFTWARE SURFACE SOFTWARE VERSION Insite File Trailer Service name.. . . . . . STSLIB. 002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/10/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name... ...... ....STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....03/10/07 Maximum Physical Record. .65535 File Type......... LO Previous File Name STSLIB.002 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11240 12731 11985.5 2983 11240 12731 ROP MWD010 FT/H 7.24 145.58 86.8835 350 12556.5 12731 GR MWD010 API 28.7 149.16 62.41 476 11240 12704 First Reading For Entire File 11240 Last Reading For Entire File 12731 REMARKS $ # Data Format Specification Record Data Record Type...... ....... 0 Data Specification Block Type 0 Logging Direction............ Down Optical log depth units. ..... Feet Data Reference Point......... Undefined Frame Spacing......... ....... 60 .1IN Max frames per record. ....... Undefined Absent value......... ........ -999.25 Depth Units.................... Datum Specification Block sub-type 0 # TOOL STANDOFF EWR FREQUENCY IN HZ ) ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12704.5 13808 13256.3 2208 12704.5 13808 ROP MWD030 FT/H 0 1405.73 70.6119 2154 12731. 5 13808 GR MWD030 API 29.06 243.44 76.2553 2120 12704.5 13781 First Reading For Entire File......... .12704.5 Last Reading For Entire File.. ..... ....13808 File Trailer Service name.. ........ STSLIB.003 Service Sub Level Name REMARKS $ # Data Format Specification Record Data Record Type............. Data Specification Block Type Logging Direction............ Optical log depth units...... Data Reference Point......... Frame Spacing................ Max frames per record........ Absent value................. Depth Uni t s . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type o o Down Feet Undefined 60 . lIN Unde fined -999.25 o # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLER'S CASING DEPTH (FT) # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN) # TOOL STANDOFF (IN EWR FREQUENCY (HZ # 000 000 000 000 Flo Pro 8.80 65.0 8.5 24000 6.2 3.750 12527.0 TOOL 82758 170 o o o o DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ') 83 95 4.3 Memory 13808.0 6 7 NUMBER ) # TOOL STANDOFF EWR FREQUENCY NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN HZ IN # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: 000 000 000 000 .0 170.0 o o Flo Pro 8.60 65.0 9.0 22000 5.6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN DRILLER'S CASING DEPTH FT 3.750 12527.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL 78012 # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE MAXIMUM ANGLE 86 90 08-FEB-03 Insite 4.3 Memory 14141. 5 5 4 NUMBER Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header BIT RUN NUMBER: 4 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START 13781 13808 DEPTH 5 5 STOP DEPTH 14114.0 14141. 5 4 5000 data for each bit run in separate files File Header Service name....... Service Sub Level Name Version Number........ Date of Generation..... Maximum Physical Record File Type......... Previous File Name STSLIB.004 1. 0.0 03/10/07 65535 LO STSLIB.003 Physical Version Number.. Date of Generation..... Maximum Physical Record File Type..... Next File Name EOF ') 1. 0.0 03/10/07 65535 LO STSLIB.004 ') Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13781. 5 14141. 5 13961. 5 721 13781. 5 14141.5 ROP MWD040 FT/H 1. 38 637.42 56.3037 667 13808.5 14141.5 GR MWD040 API 40.56 230.23 100.76 666 13781.5 14114 First Reading For Entire File......... .13781.5 Last Reading For Entire File.......... .14141.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/07 Maximum Physical Record..65535 File Type.......... .LO Next File Name..... .STSLIB.005 Physical EOF Tape Trailer Service name....... .LISTPE Date.............. . .03/10/07 Origin. . . . . . . . . . . . . .STS Tape Name.......... . UNKNOWN Continuation Number .01 Next Tape Name..... . UNKNOWN Comments. . . . . . . . . . . .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name....... .LISTPE Date.............. . .03/10/07 Origin. . . . . . . . . . . . . .STS Reel Name.......... .UNKNOWN Continuation Number .01 Next Reel Name . UNKNOWN Comments... . .STS LIS Writing Library Scientific Technical Services Physical EOF Physical EOF End Of LIS File # REMARKS $ # Data Format Specification Record Data Record Type............. Data Specification Block Type Logging Direction............ Optical log depth units...... Data Reference Point......... Frame Spacing................ Max frames per record........ Absent value................. Depth Units.................... Datum Specification Block sub-type ) o o Down Feet Undefined 60 .1IN Undefined -999.25 o )