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Home My WebLink About204-074STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CEMENT MBE ISOLATION 2. Operator Name: ConocoPhlllips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Stratigraphic❑ Exploratory ❑ Service ❑ 204-074 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23208-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1E-123 ADL 25648, ADL 25651 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,460 feet Plugs measured None feet true vertical 3,705 feet Junk measured None feet Effective Depth measured 13,457 feet Packer measured 7,749 feet true vertical 3,705 feet true vertical 3,523 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 20 108' MD 108' TVD SURFACE 3,665 feet 10 3/4 " 3,695' MD 2207'TVD INTERMEDIATE 8,012 feet 75/8" 8,041' MD 3574' TVD /C SAND LINER 5,710 feet 41/2 " 13,459' MD 3705' TVD Perforation depth: Measured depth: 7886-12822. 13144-13290 feet True Vertical depth: 3552-3670. 3692-3701 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 6,644' MD 3,182' TVD Packers and SSSV (type, measured and true vertical depth) PACKER = HRD ZXP LINER TOP PACKER 7,749' MD 3,523' TVD SSSV = NONE N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA 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:SHUT-IN Subsequent to operation: SHUT-IN - - - - 14. Attachments (required per 20 MC 25.070, 25.o7i, 8 25.283) 15. Well Class after work: Daily Report of Well Operations 17 Exploratory ❑ Development 21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-295 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Authorized Si nature: Date' 21 Contact Phone: (907) 265-6471 v Form 10-404 Revised 4/2017 I VTL �l� ��% RgDMS Submit Original Only lq AUG 2 3 2019 1 E-123 OFFSET PRODUCER FOR 1E -168L1 CEMENT MBE ISOLATION DTTM JOBTYP SUMMARYOPS START 7/24/19 ANN MIRU CTU. INSTALL BHA #12.25" OD DOWN JET NOZZLE COMM WITH XVR INTO RISER AND BOPS. PT. RIH WITH 2.25" OD DOWN JET NOZZLE WITH XVR. INTO LATERAL #1 TO 11,900' CTMD PUMPING MI SAFELUBE. POOH. JOB IN PROGRESS 7/25/19 ANN RIH WITH TAM IBP, COULD NOT GET THROUGH THE B SAND COMM WINDOW, POOH RECONFIGURE TOOL STRING, TOOK OUT ONE KNUCKLE JOINT AND PUP JOINT, RBIH SET IBP AT 10700' CTMD, POOH. MAKE UP 2006 PF HMX 2" 6 SPF 60' 5' PERF GUN, RIH LIGHTLY TAG IBP AT 10692' CTMD, PU AND PARK AT 10650', DROP .5" BALL TO FIRE GUN, SHOOT HOLES AT 10650'- 10645'. POOH, FREEZE PROTECT WELL. LAY DOWN PERF GUNS(GUNS FIRED) . RDMO. 7/26/19 ANN MI RIG UP. PERFORM WEEKLY BOP TEST. INSTALL TUBING COMM CONNECTOR. PULL TEST AND PRESSURE TEST. INSTALL BHA #1 INFLATABLE CEMENT RETAINER INTO RISER AND BOP. STAB ON WELL. 7/27/19 ANN PARK AT 10150' CTMD, DROP .5" BALL TO SET ICR, AFTER 70 COMM BBLS DID NOT SEE BALL GO ON SEAT, DROPPED SECOND .5" BALL PUMPED 68 BBLS DID NOT SEE IT GO ON SEAT. STACK DOWN -10K SURFACE WT. APPEARS ICR IS SET, GET A 5K OVER PULL ON ICR. START INJECTIVITY TEST. .5 BPM WHP 320, CTP 399 PSI, IA 500, OA 142, 1 BPM 1000, WHP 330, IA 499, OA 142. BATCHED UP 23.5 BBLS 8.6 PPG ULTRA-LITECRETE CEMENT. PUMPED 22.8 BBLS THROUGH RETAINER, TRY TO UN STING FROM RETAINER AND COULD NOT UN STING. FINALLY GOT PIPE MOVING OUT OF HOLE. AT SURFACE WE RECOVERED 2.5" BALLS AND HAD THE ICR STILL ATTACHED AND NOT INFLATED. RDMO. LEAVE WELL SHUT IN FOR MIN 3 DAYS. wcn i mAMF 1E-123 WELLBORE 1E-123 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-123 Permit to Drill Number: 204-074 Sundry Number: 319-295 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.dcska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JnlChmie/lowCskig—�' Commissioner DATED this j 4- day of June, 2019. 3BDMS146"vJUN 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN 12 ?o„ LA0 G � � 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Cement MBE Isolation D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllll s Alaska Inc. Exploratory ❑ Development Q • Shatigraphic ❑ Service ❑ 204-074 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23208-00' 7. If perforating: 8. Well Name and Number: 3 What Regulation or Conservation Order governs well spacing in this pool?NIA Will planned perforations require a spacing exception? Yes ❑ No 0 KRU 1E-123 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25648, ADL 25651 " Kuparuk River Field/ West Salk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD. Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,460' • 3,705' 13457 3705 " 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 20" 108' 108' Surface 3,665' 103/4 3,695' 2,207' Intermediate 8,012' 75/8 8,041' 3,574' Liner 5710 412 13,459' 3,705' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7886-12822, 13144-13290 3552-3670, 3692-3701 4.500" L-80 6,644' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - HRD ZXP LINER TOP PACKER 7749 MD and 3523 TVD SSSV - NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ DevelopmentE) Service ❑ 14. Estimated Date for 7/11/2019 15. Well Status after proposed work: Commencing Operations: OIL R1 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone : (907) 265-6471 Authorized Signature: � /q/ h Z �x Date: to COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I (vA(- S Plug Integrity [I SOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No m�,_ '313DMSE' JUN 18 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE � COMMISSION Date: 1l{ 16 Vi-/- / ORIGINAL Form 10-003 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate Proposed 1 E -168L1 B Sand Toe MBE Isolation with 8.6 ppg Ultra -Light Cement Procedure 1E-168 West Sak Tri-lat producer was drilled & completed in 2004. 1E -168L1 B Sd horizontal lateral has 4.5", L-80 tubing & liner set to 11927' MD. The 4.5" liner is almost entirely composed of slotted joints except for a 188' blank section at 10672 - 10860' RKB, and a 62' blank section at 7385' RKB just below the B LEM. Constrictors exist in Lnr x OH at the ends of the 188' blank. A 'B' MBE occurred 3/22/06 from 1 E-1141-1 injector to 1 E-1681-1. This MBE was treated 7/27/12 with Crystal Seal, but the treatment broke and the MBE is now open. A second MBE occurred late Dec 2018 from toe of 1 E-1681-1 to heel of 1 E-123 producer.' The wells are only —800' apart from toe of 1681-1 to heel of 123. Currently 1 E-114, 1 E-168, and 1 E-123 are all LTSI. A 4/22/19 1E -168L1 IPROF with 1E-1141-1 on PWI clearly showed entry of B MBE from 1E -114L1 at —9000' RKB, with all inflow then moving down toward the toe of 1 E-1681-1. Because the IPROF could only reach —10000', the down flow presumably goes to a toe MBE from 1E -168L1 toe at 11927' RKB to the heel of 1E-123 'B' Sd lateral. The production behaviors of 168 and 123 noted at the time of the MBE occurrence also supports this theory. Per this procedure, CT will first jet lubricant 1 E -168L1 liner with an Agitator to deep as possible while doing a Fluff & Stuff. This should help to drift & set inflatable equipment to as deep as 10700' RKB. If we can't attain 10700', we'll perform a Plan B design to set inflatable equipment further up hole. Plan A is to have CT will set an IBP in 4.5" liner at 10700' RKB in blank liner, then shoot 5' of perfs at 10645 - 10650'. CT would then set an inflatable Cement Retainer at 10150' RKB in slotted liner and pump 23.5 bbls of 8.6 ppg Cement through the Retainer to spot —600' of Cement Plug in 4.5" liner and in 4.5 x 6.75" annulus adjacent to the straddle section. Alternate Plan B job design is outlined if we need to spot a Cement Plug shallower in the liner. 1E-168 A Lat is isolated by a Plug, the B Lat is open with a Diverter set, and the D Lat is isolated with an Iso-Slv. The well is ready to perform a B Lat F&S and then execution of a Cement job to isolate the B Toe MBE. Coil Tubing Procedure: 1) Fluff & Stuff and Lubricate Slotted Liner RIH with Agitator & Nozzle BHA while jetting lubricant solution to perform Fluff & Stuff to deep as possible to clear liner of fill to enable setting an IBP at 10700' RKB in 4.5" liner, if possible. To enable Plan A, we need access to 10700' RKB, else we perform Plan B which reduces retained liner length for future PWI. POOH with BHA to PU Bridge Plug. 2) Set Inflatable Bridge Plug Perform Plan A if possible else perform Plan B. Plan A RIH with Inflatable Bridge Plug. Locate Plug at 10700' RKB near top of Blank Liner section and set Plug at 10700' RKB (optimal target). POOH. Plan B RIH & set IBP deep as possible if it can't be set at 10700' RKB. In this case the IBP will likely get set inside across liner slots if it happens to set anywhere shallower than 10672' RKB. However, IBP is designed to tolerate set in slots without compromising good set integrity. Aside from this assurance, there are no other options but to set inflatable equipment in slots to perform MBE isolation with a cement plug. The liner is all slotted above 10672' RKB. POOH. 3) Perforate Liner: If Plan A was executed (in Step 3) to set an IBP at 10700' RKB, then: RIH with Perf Gun to provide 6 spf, 60 deg ph, that yields largest avg hole diameter possible and shoot 5' CAL of perforations at 10645 - 10650' RKB (target). Perfs can be shot +/- 25' of target and be close enough to satisfy our objectives. Strict depth control is not required. POOH with perf gun. Verify ASF. If Plan B was performed in Step 3 to set IBP shallower than 10700' RKB, then: RIH with Perf Gun to provide 6 spf, 60 deg ph, that yields largest avg hole diameter possible and shoot 5' CAL of 'large hole' perforations at 275' above IBP set location. Perfs can be shot +/- 25' off target and still be close enough to satisfy our objectives. Strict depth control is not required. POOH with pert gun. Verify ASF. 4) Set Inflatable Cement Retainer (ICR) & Pump Cement: If Plan A was executed and IBP was set at 10700' RKB, then: RIH with Inflatable Cement Retainer BHA. Park ICR at 10150' RKB then pump ball with Freshwater to set ICR at 10150' RKB in 4.5" slotted liner. Strict depth control is not required. If ICR is within +/- 25' of 10150' RKB, it is close enough. Verify good ICR set and circ rate through ICR, then batch mix 23.5 bbls of'pumpable' Neat 8.6 ppg Cement. While cement is being mixed, pump 2 CT volumes (-100 bbls) Freshwater down CT at 1 bpm to thoroughly displace all hydrocarbons from straddled liner section of the liner, and the adjacent Liner x OH annulus before pumping cement to ensure no hydrocarbons (contaminant) are left in this area during cement placement. This is our first 'producer' cement job for MBE isolation, so displacing away all hydrocarbons from the horizontal area for the cement plug will be important. After 100 bbls of Freshwater has been pumped away, swap to 23.5 bbls of 8.6 ppg Cement at 1 bpm (target), followed by 5 bbls of Freshwater Spacer, followed by 5 bbls of Biozan, followed by Freshwater displacement. Displace Cement through ICR. When 22.7 bbls Cement has passed through ICR, disconnect CT from ICR, then POOH spotting the last 0.8 bbl Cement on top of ICR from 10150' to 10100' in 4.5" slotted liner, then continue POOH slowly replacing voidage with Freshwater displacement. There will be no pumping to well other than to replace voidage at 1:1 with Freshwater while POOH to surface to avoid any displacement of Cement job before set. Ensure Diesel FP in tubing to 2000' TVD. RD CTU. WOC at least 3 days. If Plan B was execute and IBP was set shallower than 10700' RKB, and perfs were shot shallower than 10645 - 10650' RKB, then: RIH with Inflatable Cement Retainer and park ICR 275' shallower in liner than where perforations were shot. Pump ball down CT with Freshwater to set ICR at XXXX' RKB in 4.5" slotted liner at depth that is 275' shallower than the perfs. Strict depth control is not required. If ICR is set within +/- 25' of target set depth, it is close enough. 2 Verify good ICR set integrity exists with good circ rate through ICR, then mix 23.5 bbls of 'pumpable' Neat 8.6 ppg Cement. While cement is being mixed, pump 2 more CT volumes (-100 bbls) of Freshwater down CT at 1 bpm to thoroughly displace all hydrocarbons from straddled liner section of the liner. After 100 bbls of Freshwater has been pumped away, swap from Freshwater to pumping 23.5 bbls of 8.6 ppg ULTRA-LiteCRETE Cement at 1 bpm (target), followed by 5 bbls of Freshwater Spacer, followed by 5 bbls of Biozan, followed by Freshwater displacement. When total of 23.5 bbls of Cement has passed through the ICR, PU & disconnect CT from the ICR, then POOH while pumping at 1:1 to replace voidage. This should leave —614' of annular cement job adjacent to —550' of Cement filled straddle inside 4.5" Liner. Ensure tubing is Diesel FP to 2000' TVD. RD CTU. WOC. If it is decided we want to flow test 1E-168 before doing a 1E -114L1 to 1E -168L1 MBE treatment, 1E -168L1 will remain SI for at least 3 days to WOC before being returned to production. l — L ^ Q r coo o r- x.- ,) m \A O N W U a) c L 1 7 O pp +-' >. �0 h 0 ,(.1 j.> O H Y O n3 O 4' a a O ,C N CO c0 +.4 Lel O vs a) '- d a c c o a a ns +, ns •c +-, ES W 4C0 a O F CI N Q p Q CW7 0 o m n r r- o a m J J r r r �., -O O In a 1. 0 V 41 d C C C C -C +.' n3 in _ C N c, c, f6 16 f6 C6 w. vs C LLJ ? ' ? 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N �+ O ro ro 0 0 o O O o o v I\ 0 0 0 0 0 0 0 N Q d' U) (-1 O c0 h co CO ++ . v, 0) 0) M co co h O ++ •- a co N N N O) N N C 0 N O 0 0 M C N N N N N N N c1 c') 6) V1 . t N 6) 6) 6) 6f 6) d ERNNONNNN CO u 0 01 O O O O O O C c 0 u pp 0 0 0 0 0 0 0 +' 4+ C O C rl C iA N cf) in in cl') N d d O C 09 &iti E CU ao d a+ Q w. Y v Ec'D E ii e 1- cu1: aj c, Q 0 n p 00 M o N COas C i i d z ++ 00 Z N M N O O - ++ E Y y 4 = a N h' P, w W O F X Z W Z 4! `� C Q O tNV W v- .- N N M C/1 yl 0 =To v C 0 3 C C CO E E OH SQ � A H a` a , 0 STATE OF ALASKA RECEIVED ALARA OIL AND GAS CONSERVATION COM•SION APR 1 1 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r 047 ~sG tdown r Performed: Suspend r Perforate p r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: ESP convert to Gaslift W. 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 204-0740 3.Address: Alaska 99510 Stratigraphic J Service P. O. Box 100360, Anchorage, 6.API Number: 50-029-23208-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025651; ADL025648 KRU 1E-123 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13460 feet Plugs(measured) None true vertical 3705 feet Junk(measured) None Effective Depth measured 13457 feet Packer(measured) 6604 true vertical 3705 feet (true vertical) 3168 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 108 108' SURFACE 3664.8 10 3/4 3694.6 2206' D-SAND WINDOW 10 7 5/8 7680 3506' INTERMEDIATE 8011.6 7 5/8 8041.4 3574' B/C SAND LINER 5710.3 4 1/2 13459 3705' Perforation depth: Measured depth: Slots: 7886-12822; 13144-13290 �T,R 2 1 20ICl True Vertical Depth: 3553-3671; 3692-3701 EQ SCW Tubing(size,grade,MD,and TVD) 4 1/2 ,L-80, 6644 MD, 3164 TVD Packers&SSSV(type, MD,and TVD) SSSV= None Packer= None 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 shut-in Subsequent to operation 520 94 1087 760 222 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development Pi Service r Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-183 Contact Darrell Humphrey/Bob Christensen Email: n1139conocophillips.com Printed Name Robert D. Christensen Title: NSK Production Engineering Specialist Signature eith Phone:659-7535 Date 41/1"/ v rL .Fig-pc Form 10-404 Revised 5/2015,, 6(M6 RBDMS L'- APR 1 1 2016 Submit Original Only • 1E-123 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/05/16 GAS MIT-IA (PASSED) TO 890 PSI. 03/08/16 DEPLOY CATCHER & PULLED DV @ 4266' RKB; ATTEMPT TO SET GLV @ SAME. IN PROGRESS. 03/09/16 SET GLV @ 4266' RKB; PULLED CATCHER @ 6593' RKB. JOB COMPLETE. 03/30/16 Opened Well - Return to Service KUP PROD 1 E-123 ConocoPhillips ° + •, Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Held Name Wellbore Status ncl(°) MD(ftKB) Act Blm(0KB) aroe rtiapn+1' 500292320800 WEST SAK PROD 92.15 8,239.83 13,460.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-123,3/15/20163.4547 PM SSSV:NONE 5 12/29/2015 Last WO: 33.61 6/16/2004 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 6,618.0 7/2/2004 Rev Reason:GLV C/O,PULLED PUMP, pproven 3/14/2016 ...........................................................__ - TUBING STOP&PACKOFF ASSY HANGER;22.2 'W': Casing Strings Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...WELen(I...Grade Top Thread CONDUCTOR 20 19.124 29.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Sot Depth(ND)...WULen(I...Grade Top Thread SURFACE 103/4 9.794 29.8 3,694.6 2,206.6 45.50 L-80 BTC-M i�'4 .q_ Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ;, INTERMEDIATE 7 5/8 6.875 29.8 8,041.4 3,573 9 29.70 L-80 BTC-M 1 I ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 0.SAND WINDOW 75/8 6.875 7,670.0 7,680.0 3,506.0 29.70 L-80 ° III Casing Descripti OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)...WULen 8...Grade Top Thread B/C SAND LINE 4 1/2 3.958 7,748.7 13,459.0 3,705.4 12.60 L-80 DWC ,:iiii Liner Detail Nominal ID Top(ftKB) lop(NO)(ft :) Top Incl(°) Item Des Com (in) CONDUCTOR;29.0-108.0 7,748.73,523.1 76.19 PACKER HRD ZXP LINER TOP PACKER 4.970 7,767. 3,527.• 76.57 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 7,770. 3,528.3 76.63 HANGER FLEXLOCK LINER HANGER 4.853 7,781. 3,530.7 76.83 SBE 190-47 CASING SEAL BORE RECEPTACLE 4.750 777,:877087001.1 ,800. 3,535.0 77.24 XO BUSHING CROSSOVER BUSHING 3.830 13,392. 3,704.0 877876...726423 8.72 BUSHING DRILLABIC: LE PACKOFF BUSHING 3.958 SURFACE;20.0-3,604.6 Tubing Strings Tubing Description (String Ma. ID lin) (Top(ftKB)22 (Set Depth(ft..f Set Depth(TVD)(...I WF (Ib/ft) (Grade (Top Connection TUBING 41 3.958 222 6,64401 3,1825 12.60 L-80 (BTM ESP MANDREL;4,266.0 I -' Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) op Incl(°) Item Des Com (in) ESP MANDREL;5,773.1 22.2 22.2 0.00 HANGER VECO GRAY TUBING HANGER 3.900 01 6,593.3 3,164.3 68.91 INTAKE CENTRILIFT 4.5"TCC XO SUB INTAKE 0.000 6,603.8 3,168.1 68.94 SEAL CENTRILIFT SEAL GSB3DBLTH6FERAFLAS 0.000 INTAKE;6,593.3 M. 6,617.5 3,173.0 68.98 MOTOR CENTRILIFT KMG 266 HP MOTOR 0.000 6,639.9 3,181.0 69.05 GAUGE CENTRILIFT A-WELL PRESSURE 8 TEMPERATURE 0.000 SEAL;6,603.8 SENSOR MOTOR;6,617.5 1` 6,642.0 3,181.8 69.06 Centralizer CENTRILIFT CENTRALIZER 4.500 `4�` Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Sot Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAUGE;8,639.9 gin, ESP PUMP 6,617.1 3,172.8 p.,_ , r:4 Perforations&Slots centre6:er 6,642.0 � } Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) BM(BOB) (ftKB) (ftKB) Zone Date t) Type Com 99861 7,886.0 12,822.0 3,552.5 3,670.5 WS C,WS B, 5/29/2004 32.0 SLOTS LOWER LINER 1E-123 D-SAND WINDOW;7,670.0- 13,144.0 13,290.0 3,692.4 3,701.0-WS B,1E-123 5/29/2004 32.0 SLOTS LOWER LINER 7,660.0 Mandrel Inserts St ati On Top(ND) Valve Latch Port Size TRO Run NL Top(ftKB) (ftKB) Make Model OD(in) Sees Type Type (in) (psi) Run Date Com 1 4,266.0 2,398.5 CAMCO KBG-2 1 ESP GLV -BK-5 0.188 1,406.0 3/9/2016 2 5,773.1 2,877.6 CAMCO KBG-2 1 ESP DMY BK 0.000 0.0 3/1/2016 Notes:General&Safety Ir, ',IEnd Date Annotation 6/16/2004 NOTE:MULTI-LATERAL WELL:MAIN LEG B/C-SAND(1E-123),0.SAND(1E-123L1) D-SAND LINER;7,665.8- 13,327.0 2/22/2009 NOTE:View Schematic w/Alaska Schematic9.0 Mk 'CI. I I I. II I, I I I I I INTERMEDIATE;29.8-8,041.4 SLOTS;7,886.0-12,822.0 SLOTS;13,144.0-13,290.0 BIC SAND LINER;7,748.7- 13,459.0 • • 8,OFTji � //j� � 49 THE STATE Alaska Oil and Gas ofZLAsKA Conservation Commission L O 5t i 333 West Seventh Avenue C Anchorage,e, Alaska 99501-3572 '� T GOVERNOR BILL WALKER g Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Robert D. Christiansen NSK Production Engineering Specialist CNN � r 1201r ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-123 Permit to Drill Number: 204-074 Sundry Number: 316-183 Dear Mr. Christiansen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P9N--1.4 Cathy . Foerster Chair DATED this 23day of March, 2016. RBDMS (,G, MAR 3 1 2016 • • RECEIVED STATE OF ALASKA MAR 0 8 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION I APPLICATION FOR SUNDRY APPROVALS G3 C�/ �l A 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Othersgonvert to Gaslift F • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development 204-0740• 3.Address: Stratigraphic r Service 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23208-00 , 7.If perforating, A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NK Will planned perforations require spacing exception? Yes r No KRU 1 E-123 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025651;ADL025648 • Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 13460 •3705 " 13457' - 3705' 1380 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79.0 20 108.0' 108' SURFACE 3664.8 10 3/4 3694.6' 2206' D-SAND WINDOW 10.0 7 5/8 7680.0' 3506' INTERMEDIATE 8011.6 7 5/8 8041.4' 3574' B/C SAND LINER 5710.3 4 1/2 13459.0' 3705' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:7886-12822; 13144-13290 • 3553-3671;3692-3701 4 1/2 L-80 6644 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSV=NONE MD= TVD= Packer=HRD ZXP LINER TOP PACKER , MD=7749 TVD=3523 12.Attachments: Proposal Summary �' WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F. Service r 14.Estimated Date for 15. Well Status after proposed work: 03/07/16 Commencing Operations: OILY WINJ 1/VDSPL r Suspended 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139(cilconocophillips.com Title: NSK Production Engineering Specialist Signature426{A.C6A____%04 Date: 3/4/// Commission Use Only (P Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` _ Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance f` Other: RBDMS 0/ MAR 3 1 2016 Post Initial Injection MIT Req'd? Yes r No IV: �./ Spacing Exception Required? Yes r No I+ Subsequent Form Required: /Q — 4 194- APPROVED BY Approved by: c.., `_—` COMMISSIONER THE COMMISSION Date:3... al_ /G ln" 3/7.z//. LY3)14/5- Submit Form and Form 10-403 Revised 11/2015 ORvIdGplicilAaiildor 12 months from the date of approva. Attachments in Duplicate • • 1E-123 • DESCRIPTION SUMMARY OF PROPOSAL 1E-123 CONVERT FROM ESP TO GASLIFT CPAI is seeking approval to convert the artificial lift method from Electric Submersible Pump (ESP) to Gaslifted production in West Sak well 1 E-123 as the ESP motor recently failed on 02/16/16 halting production. 1 E123 is a dual-lateral producer with 4-1/2" L-80 tubing was completed July 2004 in the West Sak D, C, and B sands. Converting the artificial lift method to gaslift will restore production until such time as a rig workover is deemed necessary. The well was originally completed as a packer less, single casing well, with a TTCESP set at 6593' RKB. The 4-1/2"tubing is equipped with 1" side pocket gaslift mandrels located at 4266' RKB and 5773' RKB. Follwing removal of the TTCESP, the gaslift string will be dummied off and a GMIT casing integrity test will be performed. Following a successful GMIT casing integrity test, the dummy gaslift valve located at 4266' RKB will be replaced with a 3/16" ported gas lift valve. The lift gas will enter the tubing via the existing ESP intake located at 6593' RKB. This configuration will allow the well to be operated at 1.5 MMcf/d with a stabilized operating annulus surface casing pressure of 574 psi. The kickoff pressure for the gas lift design is 1250 psi, but this would only be in the first 9 hours. KUP PRODill 1E-123 ConocoPhillips ® Well Attributes Max Angle&MD TD ° Alaska,Inc, Wellbore APUUWI Field Name Wellbore Status Mei(°) MD(ftKB) Act Bier(ftKB) rn„xeM� 500292320800 WEST SAK PROD 92.15 8,239.83 13,460.0 --, Comment H25(ppm) Date Annotation End Date KB-Grd(ft) RIO Release Date 1E-123,218/2016 4.04.24 PM SSSV:NONE 5 9/15/2010 Last WO: 33.61 6/16/2004 • Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 6,618.0 7/2/2004 Rev Reason:GLV C/O pproven 2/8/2016 HANGER:22.2 , - , Casing Strings Casing Descrlptlen OD(In) ID(In) Top(ftK5) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 20 19.124 29.0 108.0 108.0 94.00 K-55 WELDED • 1 Casing Description 01)(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread SURFACE 103/4 9.794 29.8 3,694.6 2206.6 45.50 L-80 BTC-M e eI Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 11. �i I' i INTERMEDIATE 75/8 6.875 29.8 8,041.4 3,573.9 29.70 L-80 BTC-M Casing Description 00(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WUp Len ...Grade Top Thread " ' '' !m'D-SAND WINDOW 7 5/8 6.875 7.670.0 7,680.0 3,506.0 29.70 L-80 I Casing Description OD(In) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).,.WULen(I...Grade Top Thread 8/C SAND LINER 4 1/2 3.958 7,748.7 13.459.0 3,705.4 12.60 L-80 DWC IIIII Liner Details M^w n w n n n w^ Nominal ID CONDUCTOR;28.0-1011.0 Top(ftKB) Top 1410)(ftKB).Top net(°) hem Deg Com (in) 7,748.7 3,523.1 76.19 PACKER HRD ZXP LINER TOP PACKER 4.970 7,767.8 3,527.6 76.57 NIPPLE RS PACKOFF SEAL NIPPLE 4.880 7,770.6 3.528.3 76.63 HANGER FLEXLOCK LINER HANGER 4.853 7,781.0 3,530.7• 76.83 SBE 190-47 CASING SEAL BORE RECEPTACLE 4.750 SURFACE;208-3.694.6 7,800.2 3,535.0 77.24 X0 BUSHING CROSSOVER BUSHING 3.830 13,392.9 3,704.0 88.72 BUSHING DRILLABLE PACKOFF BUSHING 3.958 ESP MANDREL,4,266.0 Tubing Strings Tubing Description (String Ma...I ID(In) (Top(ftKB) (Set Depth(ft.644.0.1 Set Depth(TVU3,182./(.5..1 WI lb/Ill 12,60(GradeL-80 (BT`Top MConnection TUBING 41/2 3.958 22.2 6; ESP MANDREL;5,773.1 Completion Details Nominal ID Top(ftKB) Top(TVD)(1160) Top Incl(°) Item Des Com (In) ! 22.2 22.2 0.00 HANGER VECO GRAY TUBING HANGER • 3.900 TBG STOP;6,540.5 6,5933 3,164.3 68.91 INTAKE CENTRILIFT 4.5"TCC XO SUB INTAKE 0.000 PACKOFF;6,543.0 6,603.8 3,168.1 68.94 SEAL CENTRILIFT SEAL GSB3DBLTH6FERAFLAS 0.000 • 6,617.5 3,173.0 68.98 MOTOR CENTRILIFT KMG 266 HP MOTOR 0.000 6,639.9 3,181.0• 69.05 GAUGE CENTRILIFT A-WELL PRESSURE 8 TEMPERATURE 0.000 SENSOR INTAKE;6.593.3 6,642.0 3,181.8 69.06 Centralizer CENTRILIFT CENTRALIZER 4.500 TTC ESP PUMP;6.594.0-. it Tubing Description String Ma...ID(In) Top(ftKB) -Set Depth(ft...Set Depth(TVD)(...WI(Iblft) Grade Top Connection SEAL,6,603.8 ESP PUMP 3.8 6,594.0 6.617.1 3,172.8 Completion Details Nominal ID MOTOR;6.617.5 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (In) • 6,594.0 3,164.5' 68.91 TTCESP 4.5"TTCESP P8 PUMP(OAL=23.11) 0.000 GAUGE',6.638.9 •i%Z;i. PUMP Centrellaer:6.642.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc) Top(ftKB) (ftoo) _ 1°) Des Com Run Date ID(In) 6,540.5 3,145.3 68.90 TBG STOP 4.5"TUBING STOP SET ON PACKOFF ASSY 10/1/2012 6,543.0 3.146.2 68.90 PACKOFF 4.5"080 PACKOFF ASSEMBLY(OAL=8.5) 10/112012 0-SAND WINDOW:7,670.0- Perforations&Slots 7,680.0 Shot Dens Top 1750) Btm(TVD) (shotsi1 Top(f11(8) Btm(ftKB) (BOB) (11KB) Zone Date I) Type Com 7,886.0 12.822.0 3,552.5 3,670.5 WS C,WS B, '5/29/2004 ' 32.0 SLOTS LOWER LINER 1E-123 13,144.0 13.290.0 3,692.4 3,701.0 WS B.1E-123.5/29/2004 32.0 SLOTS LOWER LINER Mandrel inserts I. St 0-SAN0 LINER;7665.6- at) 13,327.0 N Top(TVD) Valve Latch Port Site TRO Run Top(RKB) IItKO) Make Model OD(In) Sere Type Type (tel (psi) Run Date Com 1 4,266.0 2,398.5 CAMCO KBG-2 1 ESP DMY BK-5 0.000• 0.0 2/22/2005 2 5,773.1 2,877.6 CAMCO KBG-2 1 ESP SOV BK 0.000 2,000.0 2/6/2016 shear CI- Notes:General&Safety End Date Annotation 6/16/2004 NOTE:MULTI-LATERAL WELL:MAIN LEG B/C-SAND(1E-123).D-SAND(1E-123L1) 222/2009 NOTE:View Schematic w/Alaska Schematic9.0 I • I 1 INTERMEDIATE:29.8-8,041.4 ' , SLOTS;70860-12.622.0 SLOTS:13.144.0-13,290.0 j 1..- 1 1 13/C SAND LINER.7,748.7- 13,459.0 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. <Q 0 tJ- - 0 7 L- Well History File Identifier Page Count from Scanned File: II ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES C Ma,'a) Date7J 17/Dh If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) ~O-Sided 1111111111111111111 R~AN 'Ø' Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date: 7 J 7 0 b , I Date 7., {7/~t 3 x 30 = 00 Date 1 17 ð b I I Project Proofing BY: C Maria J Scanning Preparation BY: ~. Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed ""11111/111 111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: vYiP /5/ 1/1 II 1/1/11 11111111 /5/ V\1 r + d.v ~ = TOTAL PAGES II ~ (Count does not include cover sheet) /AA P /5/ " , 1111111111I111 ,,11/ NO /5/ W1f NO /5/ 111111/111111111111 1111111111111111111 /5/ Quality Checked 11111111/11I111111I 10/6/2005 Well History File Cover Page.doc • • . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 15, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 f$ t ) PI c i 14 Anchorage, AK 99501 a0 07 Commissioner Dan Seamount: 1 E. _ g3 Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor /sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 5/15/2012 1C,1D,1E,2L,3H PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement , pumped cement date inhibitor sealant date ft bbls ft gal 1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E -123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L -304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L -319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 3H -17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 • ~onocoP h~liips Alaska P.O. BOX 100360 ANCHORAGE, All15KA 99510-0360 August 17, 2008 ~~~ AU G ~ ~ 200$ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7t1i Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • AUG 2 5 2008 Alaska Oi! & Gas Cans, X00'1 r~ !i;;SiOn Anchorage ~~~y-- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to Flling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ._._..__....._-__- ~ ~ Z ~~~ ~ ConocoPhillips Well Integrity Projects Supervisor ., r~ ~~ ConocoPhillip§ Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top c date ft bbls ft 2H-05 185-168 SF N/A SF N/A 2H-17 200-019 8" N/A 6" N/A 2K-27 201-169 10" N/A 10" N/A 2M-03 191-141 16" N/A 16" N/A 1 B-14 194-030 SF N/A SF N/A 1 B-18 194-061 9" N/A 9" N/A 1 B-19 194-064 SF N/A SF N/A 1B-20 203-115 21" N/A 21" N/A 1B-101 203-133 3" N!A 3" N/A 16-102 203-122 4" N/A 4" N/A 1Y-05 183-087 6" N/A 6" N/A 1 Y-07 183-068 6" N/A 6" N/A 1Y-17 193-068 SF N/A SF N/A 1Y-22 193-070 SF N/A SF N/A 1Y-26a 188-116 SF N/A SF N/A 1Y-30 188-090 SF N/A SF N/A 1E-112 204-091 14" N/A 14" N/A 1E-119 204-031 14" N/A 14" N/A 1 E-121 204-246 6" N/A 6" N/A 1 E-123 204-074 5" NIA 5" N/A 8/17/2008 ff Corrosion inhibitor Corrosion inhibitor/ sealant date al 5.10 8/2/2007 1.27 8/2/2007 8.92 $/2/2007 2.13 8/2/2007 1.70 8.07 8!1312008 8/13/2008 5.10 8!13/2008 5.95 8/13/2008 1,00 8/17/2008 1.00 8/17/2008 1.27 8/13/2008 1.27 1.27 8!13/2008 8/13/2008 2.12 8/13/2008 3.83 8/13/2008 3.83 8/13/2008 5.95 8/17/2008 4.67 8!17/2008 1.00 8/17/2008 1.00 8/17!2008 • • ;;=` ;. MICROFILMED 03/01/2008 DO NOT PLACE ~~° w- ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc \ \ç J~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040740 Well Name/No. KUPARUK RIV U WSAK 1E-123 Operator CONOCOPHILLlPS ALASKA INC S'p~¿ /, no¡ ~ y API No. 50-029-23208-00-00 MD 13460 ____ TVD 3705"'- Completion Date 6/16/2004"'- Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Directional surve~ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlReslDens/Neutron (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ :ze Med/Frmt Number Name Scale Media No Start Stop CH Received Comments pt Directional Survey 11892 13460 6/25/2004 ~pt Directional Survey 0 12132 6/25/2004 PS1 .,.-ÆD C Pdf 12763 Induction/Resistivity 108 12132 10/8/2004 PS1, RWD-GRlMPR ~ 12763 LIS Verification 108 12132 10/8/2004 PS1, RWD-GRlMPR Cog 12763 LIS Verifi~atiQn j ."J.~.,\s-~ ~ Slu 108 12132 10/8/2004 PS1, RWD-GRlMPR ~g 12763 LtC 'krili...ätlon r 1I\~.itu-v- t<t.f Slu 108 12132 10/8/2004 PS1, RWD-GRlMPR yvc Lis 12775 Induction/Resistivity 108 13460 9/21/2004 LIS TIF MULTIPLE PROPAGATION RESISTIVITY GAMMA RAY, RWD, GRAPHIC IMAGES ~g 12775 Induction/Resistivity Slu 108 13460 9/21/2004 LIS TIF MULTIPLE PROPAGATION . RESISTIVITY GAMMA RAY, RWD, ~g 12775 I nd uction/Resistivity Slu 108 13460 9/21/2004 LIS TIF MULTIPLE PROPAGATION RESISTIVITY GAMMA ~ RAY, RWD, 12775 LIS Verification Slu 108 13460 9/21/2004 LIS TIF MULTIPLE PROPAGATION RESISTIVITY GAMMA RAY, RWD, Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2040740 MD 13460 TVD 3705 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~ Analysis Received? :t.J,ÞV Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. KUPARUK RIV U WSAK 1E-123 Operator CONOCOPHILLlPS ALASKA INC Completion Date 6/16/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? &/N ~/N Formation Tops )~ Date: _ API No. 50-029-23208-00-00 UIC N )J~~ ~ ~ . . . . Tom, Here is the well orientation plot for the 1320 requested on IE-114. Also, included are the cementing reports for each one of these wells. Six wells were seen -to intersect the 1320 plot: 1E-168 v ~). o,--\-";)··a¿) '\ 1E-123./ ;]·û'--\.-Q""\ '\ "'~o\~~J <61~ -OLt * \ £: -\¿~ L.1.-. êKJ..t-O'1ç 1D-116 ../ ,s,<'¿- \,~.) 1D-113 ~ ,~~- \',\ ~. 1D-112./ \<1., ~- \'6~, c 1 D-103 .;)0 ð' - Oq (..;; - <è "-N\ ;.J c:..:-\i{0 i ¡, S -0 ~ All the wells had good cementing operations with the exception of 1D-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 ·T~"·\5 'JðC.Ù~C'"\\- ~GL7 ~5\-"\ û\ -\~ ~L\4£\ Ò-~;>S~<,~~c¿~··.çðr ~xTTI: ·~O\ \ t: - \ \ ~ t-l~l.. ~.' -- L)~ l\'&\;ð'\'0\~~~ \ ~º\~~CD~~ \--.0"" \We:~' ç' \o.Œ2J\ '" .\-\r-e WS-F \-tv~o .ç:~ \ ~... ~. t \ ~~Q.\\.> \J"-J C~(t c¿)Q ~\--¡jI-,(\r!~J ·\0 \"OJE- CJ.c:.cq)~1t> \e< \\"~Jr-~ ~ ' ~9-~~ ^ ~ ¿)--¡ l c~O ..::> 7000- / //', 1 / / (J '" " ~ '" '" if " / ~f I Kul Kuparuk lE Pad, lE-123, IE-123 v2/1 / I ff I , """. ./ I Kuparuk ID Pad, ID-I03, ID-I03 VI I ANTI-COLLISION SETTINGS 6000- ,~ ¡ 3538 I ¡ 3598 ¡ ¡ .1 I Kuparuk IE Pad, lE-168, lE-168 VI I I ~ 3598 I Kuparuk ID Pad, ID-112, ID-112 V2 l ",III I Kuparuk IE Pad, lE-I lE-114 l I Interpolation Method:TVD Interval: 1.000 Deplh Range From: 3478.000 To: 3788.250 Maximum Range: 1376.200 Refereoce: Definitive Swvey eonocÓPhillips +' ~ o ~ £ ::s o rn 2000- , , , , , , 5000- 4000- '2 ;¡'§ o o o ~ 3000- 3718 1000- / ~ 3718 I Kuparuk ID Pad, I D-116, ID-116 V2 l ~~ 3658 ", , f'-. , C " 3598 ',"11 I 718 3538 - 3718 ---:3478 .. i3~ / - "13;;~ ./ ~ ~~: ~ Circles of 1320' Radius 0-, ", J 0- r.., ~ I 3000 " J Kupai~JE Pad, I~ Kuparuk IE Pad, ~ lE-33 V2 III ~4' _~ 10" ' I K.uparuk I~ E-24, IE-24A VJ r.." ", I I I ~# I I I -1 ('-'--1 I ì 4000 5000 6000 7000 W est( - )Æast( +) [I OOOWin] I 8000 =-......__ ·.....v-!5Un þ.... L.tNG .."vle.. ~ "~...u,,·tI,,.~ .~.~"''\."... . 'C ... j f'\ '7. / L -, I 7'~ . ¢J ~ Q ConocoPhillips Alaska Daily Drillin~ Report 24 Hrs Network Prog Page 1 of 2 . P Al Daíly Drilling r- ConocÓPhillips -, lE-123 lE-123 10032919 0' 8,047' 3,574' 7.4 9 DATE 5/23/2004 Well Sidetrack TMD TVD DFS REPT NO. Supervisor Herbert / Proposed TMD 0' Pressure Test(s} Lowe Rig Name Doyon 141 Daily Cost $138,863 Type' Date' TMD , TVD , MW , Press I Tot. press , EMW Field LOT 15/21/200413725'12205'19.31 Name West Sak Cumulative Cost $1,637,839 ppg766 psill,832.42 psi116.00 ppg Circ & Cond Current mud with csg Last Safety BOP Tst 5/20/2004 I 5/27/2004 Status on bottom, Meeting 5/20/2004 (Last, Next) prep. to pump cement Event Code 24HR Forecast ODR Incident 1st 24 hrs? No Rig Accept: 5/16/2004@ 00:00 Rig Release: @ : C&C mud, cement csg, pressure test csg, PU SHA, RIH Last Survey 5/22/2004 TMD: INC: Azim: Last Casing 7.625 (in) @ 8042 Next Casing 8,009 84.2 3.8 4.5 (in) @ 13345 Operations Summary From To Hours Phase ActivitySubcode ~::~ Trouble ~~:~ :e~~h Operation Continue to backream from 7,459' to 7,181'. Worked thru tight spots from 7,300' - 7,181'. Well started 00:0001:00 1.00 INTRMl DRILL REAM P 7,459' 7,645' unloading excess cuttings (3x cuttings rate over the shakers as when it was drilled). RlH to 7,645', below the first tight. 01:0001:30 0.50 INTRMl DRILL CIRC P 7,645' 7,645' CIBU, .until returns started c eanmg up. Backream form 7,695' - 01 :3003:00 1.50 INTRMl DRILL REAM P 7,645' 6,995' 6,995' at 150 rpm and 635 GPM, w/o problems. Pump 35 bbl of Hi-Vis / 03:0004:00 1.00 INTRMl DRILL CIRC P 6995' 6995' weighted sweep and , , circulate. (10% increase in cuttings). Flow check - static. POOH on 04:0007: 15 3.25 INTRMl DRILL TRIP P 6,995' 3,653' elevators from 6,995' - 3,653'. Hole taking proper fill. Flow check f/15 min. POOH and LD 28 stds of 5" DP, Ghost reamer, 29 Jts of 07:1511:00 3.75 INTRMl DRILL TRIP P 3,653' 0' http://partners.conocophillipsalaska.comldrilling/cgi -bin/reports/daily .asp ?wellname= 1 E %... 5/25/2004 , PAIlJally lJrilling Page 2 of2 . HWDP, BHA. 3,653' 0' Download MWD, LD same. 0' Pull WB, set test plug. Change out top set of pipe 0' rams to 7-5/8" and tested to 3,500 psi. 0' Make Dry run with landing joint and csq hngr. 0' RU equipment for 7-5/8" csg. PJSM. Run casing to 3,690'. 0' 3,690' Up Wt = 127K, Dwn Wt + 69K. 3,690' 0' Circulate casing, staging up to 5 BPM and 325 psi. 3,690' 3 690' Change out sealing cup on , Frank's Tool. Run casing in open hole to 3,690' 5,138' 5,128. Avg MU TQ = 9,000 ft-Ib. 24 Backream out of hole to the 10-3/4" csg shoe, circulate, POOH, LD 5" DP and BHA. RU and run 7-5/8" Hr. csg, break cire at 10-3/4" shoe, change out damaged packoff on Frank's tool. Continue to RIH to Sum: 5,900', break eire. . 11:0012:00 1.00 INTRM1 DRILL 12:0012:45 0.75 INTRM1 WELCTL PULD OTHR P P 0' 12:4513:45 1.00 INTRM1 WELCTL BOPE P 0' 13:4514:00 0.25 INTRM1 CASE OTHR P 0' 14:0015:00 1.00 INTRM1 CASE RURD P 0' 15:0020:30 5.50 INTRM1 CASE RUNC P 20:3021:45 1.25 INTRM1 CASE CIRC P 21:4522:30 0.75 INTRM1 CASE CIRC P 22:3000:00 1.50 INTRM1 CASE RUNC P Mud Data Mud 10sec / 10 Flowline Drilling Company Type Density FV PV /YPmin / 30 min WL/HTHP MBT PH Temp Solids Gels M-I Drilling LSND 9 40 10/ 14 5/8/10 5.4 / 0 12.5 8.4 65 1.2 Fluids M-I Drilling LSND 9.2 54 16 / 25 12/15/17 5/0 17.5 9 72 2 Fluids Bits Bit/Run Size Manuf. Type Serial Jets 1-6 TFA Depth Date In I-O-D-L-B-G-O-R No. In FS2653 5013150 16-16-16-16- 1.178 3705' 5/20/2004 1-2-WT- A-D-I- BT- 16-16 in2 TD 2/5 9.875 SEC ~ http://partners.conocophillipsalaska.comldrilling/cgi -bin/reports/daily .asp ?wellname= IE %... 5/25/2004 , PAl Daily Drilling . r ConocÓPhilUps Well Sidetrack 1E-123 1E-123 . ¢ ~ c> ConocoPhillips Alaska Daily Drillin~ Report Network 24 Hrs TMD TVD Prog Page I of 3 ~ DFS REPT NO. 5 DATE 5/19/2004 10032919 0' 3,705' 2,209' 3.4 Pressure Test(s) Type Date TMD TVD MW Press Tot. press EMW 110'10'10 ppglO psi 1 0.00 psi I 0.00 $1,090,298 ppg BOP Tst 5/19/2004 (Last Next) Rig Accept: 5/16/2004@ 00:00 Rig Release: @ : Supervisor Herbert/Thornton/Lowe Proposed TMD Rig Name Doyon 141 Field Name Current Status Event Code 24HR Forecast West Sak Nipple up BOPE. ODR 0' Daily Cost $365,494 Cumulative Cost Last Safety Meeting Incident 1st 24 hrs? No N/U & Test BOPE, P/U D.P.& BHA, LOT, Drill 9-7/8" hole. Operations Summary . . Time Start End Hours Phase ActlvltySubcode Class Trouble Depth Depth Operation POOH on elevators f/ 2,400' to 890' (Worked thru tight 1,092' 890' spot f/ 952' to 922'- Wipe through same several times f/ 1002' to 890'). Stand back HWDP, Lay down 0' Flex collars, Stab, MWD, Motor, Bit, Clear rig floor. Rig to run 10-3/4" casing, Make dummy run with Veto 0' Gray 18-3/16"x 10-3/4" casing hanger, PJSM with all crew members. Last Survey TMD: 5/22/2004 8,009 From To 00:0001:00 1.00 SURFAC DRILL 01 :00 04:00 3.00 SURFAC DRILL 04:0006:00 2.00 SURFAC CASE 06:0014:30 8.50 SURFAC CASE INC: Azim: Last Casing Next Casing 84.2 3.8 10.75 (in) @ 3694 7.625 (in) @ 7902 TRIP P 0' 0' Run 10-3/4" Weatherford Float shoe, 2 jts 10-3/4", 45.5#, L-80, BTC csg, Weatherford Aoat collar, 87 jts 10-3/4", 45.5#, L-80, BTC csg, Veto Gray 18-3/16"x 10- 3 694' 3/4" casing hanger, Ran 10- , 3/4"x 15-7/8" Bow spring centralizers as follows= 1-10' above shoe, On collar between jt. #1 & #2, 1-10' below float collar, 1-20' above float collar, 1 every 30' on stop rings for 12 jts., 1 on PULD 890' http://partners.conocophillipsalaska.comldrilling/cgi -bin/reports/daily .asp ?wellname= IE %... 5/2412004 p RURD p RUNC p , PAl Daily Drilling Page 2 of 3 . . every collar on jts # 12 thru #20, Total of 22 centralizers and 12 stop rings. Pump & work thru tight spot @ 960', Wash down to 1,321', Then continue to RIH to btm Float shoe @ 3,694.60', Float collar @ 3,610.75'. Circ btm's up with Frank's fill 14:3015:30 1.00 SURFAC CEMENT CIRC P 3,694' 4' up tool at rate of 3 bpm @ 3,69 400 psi, Reciprocate csg 15'- UP 160K, DN 90K. 15:3016:00 0.50 SURFAC CEMENT PULD P 3,694' 3 694' Lay down Frank's fill up tool, , Rig up Dowell cement head. Continue to condition mud for cement, Stage rate up to 7 16:0017:45 1.75 SURFAC CEMENT CIRC P 3,694' 3 694' bpm @ 550 psi, Final mud , properties 9.6 ppg, 49 vis, PV 17 YP 14, Gels 3/5, PH 8.4, Hold PJSM for cmt job. Rig Dowell, Mix & pump 5 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 400 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.5 bpm @ 165 psi, Shut down and drop btm plug, Mix & pump 723 sxs (573.7 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wi additives at rate of 6.4 bpm @ 200 psi, Followed by 214 sxs (95.1 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg wi additives at rate 17:4522:00 4.25 SURFAC CEMENT PUMP P 3,694' 3,694' of 6.9 bpm @ 340 psi, Shut down and drop top plug, Displace cmt wi 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wi 321.6 bbls 9.6 ppg mud (total of 341.6 bbls to bump plug) at rate of 7.0 bpm @ 600 to 730 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug wi 1000 psi, Floats held- OK, CIP @ 21:48 hrs 5/19/04, Had good returns thru out job, Reciprocate csg. 15' until MudPUSH at surface then pipe began taking wt., Had 222 bbls good cmt returns to surface. 22:0022:30 0.50 SURFAC CASE MIT P 3,694' 3 610' Test casing to 2500 psi for 30 , min. on chart- OK. Rig down Dowell cement 22:3000:00 1.50 SURFAC CEMENT RURD P 3,610' 0' head, Flush riser and flow line, Rig down casing equip. 24 Hr. POOH & LID BHA, Rig & run 10-3/4" csg to 3,694', Circ & cond mud, Cmt csg wi 222 bbls cmt to http://partners.conocophillipsalaska.com/drilling/cgi -bin/reports/daily .asp ?wellname= 1 E %... 5/2412004 , PAl ually Unllmg Page j ot j . ISum:~urface, Bump plug & test csg to 2500 psi, Flush out riser, RID csg .p. Mud Data Mud 10see / 10 FlowLine Drilling Company Type Density FV PV/YPmin / 30 min WL/HTHP MBT PH Temp Solids Gels M-I Drilling Spud 9.6 49 17 114 3/5/7 5.8/0 25 8.4 60 1.5 Fluids Mud M-I Drilling Spud 9.6 42 13/9 3/5/8 5.4 I 0 25 9 69 1.5 Fluids Mud Bits Bit/ Run Size Manuf. Type Serial Jets 1-6 Depth TFA Date In I-O-D-L-B-G-O-R No. In 1rr3/4 13.5 HTC MXC-1 5050369 18-18-18-13- 0.875 2103' 5/18/2004 2-2-WT- A-E-I- EC- 0-0 in2 TD ~ ~ http://partners.conocophillipsalaska.comldrillinglcgi -bin/reports/daily. asp ?wellname= 1 E %... 5/24/2004 Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 2 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/24/2004 End: Hole Size: 9.875 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,041 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/24/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate CasinglLi sa Type: Csg Type: Plug Date: Csg Size: 7.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Intermediate CasinglLi Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpeper Pipe Movement: No movement Rot Time Start: Rec Time Start: Time End: Time End: RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Type: Cement Casing Volume Excess %: 60.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 252 (gpm) Mud Circ Press: 550 (psi) Start Mix Cmt: 08:25 Start Slurry Displ: 08:25 Start Displ: 09:03 End Pumping: 10:13 End Pump Date: 5/24/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.60 (bbl/min) 6.80 (bbl/min) Y 1,050 (psi) 1,700 (psi) 5 (min) Y Retums: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: LSND Density: 9.0 (ppg) Vise: 38 (sIqt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVNP: 11 (cp)/12 (lb/100ft2) Gels 10 see: 4 (lb/10Qft2) Gels 10 min: 6 (1b/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.0 (ppg) Volume: 361.70 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: 2,960.00 (ftJro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: CW100 4,005.00 (ft) Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 7/7/2004 1:13:11 PM Legal Well Name: 1E-123 Common Well Name: 1 E-123 Event Name: ROT - DRILLING Report #: Start: Spud Date: 5/17/2004 Report Date: 5/24/2004 End: 2 5/15/2004 Slurry Data Fluid Type: FLUSH Slurry Interval: 4,005.00 (ft¡ro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: 5,050.00 (ft) Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft31sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 5,050.00 (ft¡ro: Water Source: Test Data Thickening Time: 5.03 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Description: DeepCRETE Class: G 8,041.00 (ft) Cmt Vol: 186.4 (bbl) Density: 12.50 (ppg) Yield: 2.30 (ft3/sk) Slurry Vol:455 (sk) Water Vol: 84.0 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 7.75 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) D46 8160 D167 D186 0.60 %BWOC 0.60 %BWOC 0.30 %BWOC 0.02 G P S Printed: 7/712004 1:13:11 PM Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 2 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/24/2004 End: Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: CementTop: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.3 bpm @ 240 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 5.5 bpm @ 220 psi, Shut down and drop btm plug, Mix & pump 455 sxs (186.4 bbls) Tail DeepCRETE cmt mixed at 12.5 ppg w/ additives at rate of 6.0 bpm @ 300 psi, Shut down and drop top plug, Displace cmt w/20 bbls fresh water, Shut down and tum over to rig pumps and continue to displace wI 341. 7 bbls 9.0 ppg mud (total of 361.7 bbls to bump plug) at rate of 6.5 bpm @ 200 to 930 psi, Slowed rate to 3.5 bpm @ 1050 psi for last 10 bbls of displacement, Bump plug wI 1700 psi, Floats held- OK, CIP @ 10:15 hrs 5/24/04, Had good retums thru out job, Unable to reciprocate casing due to excessive up and down drag with 84.2 deg. deviation. UP 240K, DN 55K, Blocks 35K. Printed: 7f712004 1: 13: 11 PM . . :'~?" Conoc:õPhUlips M<ïS!<a,lnc; Well: 1E-123 Date: 5/23/2004 DEPTH LENGTH TOPS Casing Detail 7-5/8" Intermediate CasinQ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 11 to 188 Jts 10 to 1 0 Jts 3 to 9 Jts 1 to 2 178 Jts 1 Jts 7 Jts 2Jts RKB Doyon Rig 141 to Landing Ring ABB Vetco Gray 10-3/4" x 7-5/8" Casing Hanger & Pup jt. 7-5/8", 29.7ppf, L-80, BTC-M Casing Pup Joint 7-5/8", 29.7ppf, L-80, BTC-M Casing Pup Joint 7-5/8", 29.7ppf, L-80, BTC-M Casing 7-5/8", 29.7ppf, L-80, BTC-M Casing Window Joint 7-5/8", 29.7ppf, L-80, BTC-M Casing Weatherford Model 402 Sure Seal Float Collar 7-5/8", 29.7ppf, L-80, BTC-M Casing Weatherford Model 303 Sure Seal Float Shoe Bottom of Shoe @ --------»» TD of 9-7/8" Hole = 8,047' MD 3,575' TVD 7-5/8" Shoe = 8,042' MD 3,574' TVD ( 5' Rathole) Total Centralizers Used (1ea) 7-5/8"x10-1/2" Tandem Rise Cent on Stop Collar 10' above sho (1ea) 7-5/8"x10-1/2" Tandem Rise Cent on Csg Collar of shoe joint (1ea) 7-5/8"x10-1/2" Tandem Rise Cent on Stop Collar 10' above FC (1ea) 7-5/8"x10-1/2" Tandem Rise Bowspring Cent on each csg colla On joints 3-18, (excluding the window joint -#10) Bow spring Centralizer on Stop Collars every 3D' for jts 19-25 200 joints in Shed 12 joints out Run 188 joints total Ran 188 joints of casing. Drifted casing to 6.75" plastic drift. Used Run-N-Seal thread compound on all connections. Supervisor: Fred Herbert / Mike Thornton 29.82 2.94 10.10 20.17 7552.74 42.57 299.75 1.34 80.43 1.51 UpWt DnWt Block Wt 29.82 32.76 42.86 63.03 7615.77 7658.34 7958.09 7959.43 8039.86 8041 .37 240K 55K 35K Legal Well Name: Common Well Name: Event Name: 1 E-123 1 E-123 ROT - DRILLING Report #: Start: 1 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/19/2004 End: String Type: Surface Casing Permanent Datum: Kelly Bushing Hole Size: 13.500 (in) Hole TMD: 3,705.0 (ft) Hole TVD: 2,209.0 (ft) KB-Datum: 71.00 (ft) Water TMD: (ft) Str Wt on Slips: 143,000 (Ibs) . Ground Level: 70.70 (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 75.30 n Circ Hours: 2.25 (hr) Mud Lost: (bbl) KB to Cutoff: 29.82 (ft) Days From Spud: 3.40 (days) Manufacturer: Vetco Gray Hanger Model: Actual TMD Set: 3,694.60 (ft) Model: Producer Packoff Model: Top Hub/Flange: (in) I 5,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) Casing Hanger 10.750 1 3.44 29.82 Casing Hanger Casing 10.750 45.50 L·80 9.794 87 3,577.49 33.26 9.950 103/4" 45.5# L-8 Float Collar 10.750 1 1.47 3,610.75 Float Collar Casing 10.750 45.50 L·80 9.794 2 80.63 3,612.22 9.950103/4" 45.5. Float Shoe 10.750 1 1.75 3,692.85 Float Shoe 3,694.60 Bowspring Centralizer WEATHERFORD 1 3,684.0 3,684.0 Stop Ring Bowspring Centralizer WEATHERFORD 1 3,652.0 3,652.0 OverCollar Bowspring Centralizer WEATHERFORD 1 3.620.0 3,620.0 Stop Ring Bowspring Centralizer WEATHERFORD 1 3,590.0 3,590.0 Stop Ring Bowspring Centralizer WEATHERFORD 9 3.590.0 3,207.0 Stop Ring Bowspring Centralizer WEATHERFORD 8 3.207.0 2,878.0 OverCollar Printed: 7/7/2004 1:12:59 PM Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 1 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/19/2004 End: Run 10-3/4" Weatherford Float shoe, 2 its 10-3/4",45.5#, L-80, BTC csg, Weatherford Float collar, 87 its 10-3/4",45.5#, L-80, BTC csg, Veto Gray 18-3/16"x 10-3/4" casing hanger, Ran 10-3/4"x 15-7/8" Bow spring centralizers as follows= 1-10' above shoe, On collar between it. #1 & #2,1-10' below float collar, 1-20' above float collar, 1 every 30' on stop rings for 12 its., 1 on every collar on its #12 thru #20, Total of 22 centralizers and 12 stop rings. Pump & work thru tight spot @ 960', Wash down to 1,321', Then continue to RIH to btm Float shoe @ 3,694.60', Float collar @ 3,610.75'. . . Printed: 7/7/2004 1:12:59 PM Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 1 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/19/2004 End: Hole Size: 13.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 3,695 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 5/19/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 10.750 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: David Walber Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:14:30 Time End: : Time End: 21 :00 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 160,000 (Ibs) Drag Down: 90,000 (Ibs) Type: Cement Casing Volume Excess %: 250.00 Meas. From: 222.0 Time Circ Prior To Cementing: 2.75 Mud Circ Rate: 294 (gpm) Mud Circ Press: 550 (psi) Start Mix Cmt: 19:00 Start Slurry Displ: 21 :09 Start Displ: 21 :09 End Pumping: 21 :48 End Pump Date: 5/19/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbVmin) Y 500 (psi) 1,000 (psi) 5 (min) Y Retums: Full Total Mud Lost: (bbl) Cmt Vol to Surf: 222.00 (bbl) Ann Flow After: N Mixing Method: Tub Density Meas By: Densometer Type: Spud Mud Density: 9.6 (ppg) Vise: 49 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PV/yP: 17 (cp)/14 (lb/100fF) Gels 10 see: 3 (1b/10Oft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: CF) Density: 9.6 (ppg) Volume: 341.60 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: CF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 7/7/2004 1: 13:30 PM Legal Well Name: 1E-123 Common Well Name: 1 E-123 Event Name: ROT - DRILLING Report #: Start: 1 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/19/2004 End: Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Description: ARCTIC SET Class: G To: 3,060.00 (ft) Cmt Vol: 573.7 (bbl) Density: 10.70 (ppg) Yield: 4.45 (ft3/sk) Slurry Vol:723 (sk) Water Vol: 356.7 (bbl) Other Vol: () Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: eF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp eF) (OF) Purpose: PRIMARY Mix Water: 20.72 (gal) Foam Job: N Pressure (psi) (psi) S002 D124 D65 D53 D46 D79 D44 1.50 %BWOC 50.00 %BWOC 0.50 %BWOC 30.00 %BWOC 0.60 %BWOC 1.50 %BWOC 9.00%BWOW Slurry Data Fluid Type: TAIL Slurry Interval: 3,060.00 (ft}ro: Water Source: Test Data Thickening Time: 3.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: DeepCRETE Class: G 3,694.00 (ft) Cmt Vol: 95.1 (bbl) Density: 12.00 (ppg) Yield: 2.49 (ft3/sk) Slurry Vol:214 (sk) Water Vol: 44.9 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: TAIL Mix Water: 8.83 (gal) Foam Job: N Pressure (psi) (psi) Printed: 71712004 1:13:30 PM Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 1 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/19/2004 End: D46 B160 D186 0.60 %BWOC 0.17%BWOC 0.25 G P S Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: CementTop: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Rig Dowell, Mix & pump 5 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 400 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.5 bpm @ 165 psi, Shut down and drop btm plug, Mix & pump 723 sxs (573.7 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI additives at rate of 6.4 bpm @ 200 psi, Followed by 214 sxs (95.1 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg wI additives at rate of 6.9 bpm @ 340 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and tum over to rig pumps and continue to displace wI 321.6 bbls 9.6 ppg mud (total of 341.6 bbls to bump plug) at rate of 7.0 bpm @ 600 to 730 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug wI 1000 psi, Floats held- OK, CIP @ 21:48 hrs 5/19/04, Had good returns thru out job, Reciprocate csg. 15' until MudPUSH at surface then pipe began taking wt., Had 222 bbls good cmt retums to surface. Printed: 71712004 1:13:30 PM ~..'. ConocoPhiUips M~k¡';'nc. Jt Number Num of Jts Jts 3 to 89 87 Jts Jts 1 to 2 2Jts . .. Casing Detail 13-3/8" Surface Casina COMPLETE DESCRIPTION OF EQUIPMENT RUN RKB Doyon Rig 141 to Landin~ Ring ABB Vetco Gray 18-3/16 X 10 3/4" Casing Han~er & Pup jt. 103/4",45.5 ppf, L-80, BTC Casing Weatheñord Model 402 Sure Seal Float Collar 103/4",45.5 ppf, L-80, BTC Casin~ Weatheñord Model 303 Sure Seal Float Shoe Bottom of Shoe @ --------»» TD of 13-1/2" Hole = 3705' MD 2209' TVD 103/4" Shoe = 3694' MD 2205' TVD (10.40' Rathole) Total Centralizers Used Run 1 10-3/4"x 15-7/8" Bow sprinQ Centralizer on Stop Collar 1 1 Bow sprinQ Centralizer on collar between its. #1 & 2 Run 1 Bow sprinQ Centralizer on Stop Collar 10' below F.C. Run 1 Bow sprinQ Centralizer 20' above F.C. Run 1 Bow spring Centralizer on Stop Collars every 3D' for 12 jts. Run 1 Bow spring Centralizer on Collars #12 thru #20. Total of 22 Centralizers and 12 Stop collars 98 joints in Shed 9 joints out Run 89 joints total Ran 89 joints of casing. Drifted casing to 9.875" plastic drift. Used Run-N-Seal thread compound on all connections. Supervisor: Fred Herbert / Mike Thornton Well: 1E-123 Date: 6/28/2004 DEPTH LENGTH TOPS 29.82 3.44 3577.49 1.47 80.63 1.75 UpWt DnWt Block Wt 29.82 33.26 3610.75 3612.22 3692.B5 3694.60 160K 90K 35K Legal Well Name: Common Well Name: Event Name: 1E-123 1 E-123 ROT - DRILLING Report #: Start: 2 5/15/2004 Spud Date: Report Date: End: 5/17/2004 5/24/2004 String Type: Intermediate Casing/Liner Permanent Datum: Kelly Bushing Hole Size: 9.875 (in) Hole TMD: 8,047.0 (ft) Hole TVD: 3,574.0 (ft) KB-Datum: 71.00 (ft) Water TMD: (ft) Str Wt on Slips: 203,020 (Ibs) . Ground Level: 70.70 (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 84.20 (0) Circ Hours: 5.50 (hr) Mud Lost: (bbl) KB to Cutoff: 29.82 (ft) Days From Spud: 8.40 (days) Manufacturer: Vetco Gray Hanger Model: Actual TMD Set: 8,041.37 (ft) Model: Producer Packoff Model: Top Hub/Flange: (in) I 5,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) Casing Hanger 7.625 1 2.94 29.82 Casing Hanger Casing - Pup Jt 7.625 29.70 L-80 6.750 BTC 1 10.10 32.76 6,875 75/8" 29.7# L-8 Casing - Pup Jt 7.625 29.70 L-80 6.750 BTC 1 20.17 42.86 6.875 7 5/8" 29.7# L·8 Casing 7.625 29.70 L-80 6.750 BTC 178 7,552.74 63.03 6.875 75/8" 29.7. Window Joint 7.625 29.70 L-80 6.750 BTC 1 42.57 7,615.77 6.875 7 5/8" 29.7 Casing 7.625 29.70 L-80 6.750 BTC 7 299.75 7,658.34 6.875 7 5/8" 29.7# L-8 Float Collar 7.625 1 1.34 7,958.09 Float Collar Casing 7.625 29.70 L·80 6.750 BTC 2 80.43 7,959.43 6.875 7 5/8" 29.7# L-8 Float Shoe 7.625 1 1.51 8,039.86 Float Shoe 8,041.37 Tandem Rise Centralizer Tandem Rise Centralizer Tandem Rise Centralizer Tandem Rise Centralizer WEATHERFORD WEATHERFORD WEATHERFORD WEATHERFORD 1 1 1 14 8,031.0 8,000.0 7,948.0 7,285.0 8,031.0 Stop Ring 8,000.0 OverCollar 7,948.0 Stop Ring 7,875.0 OverCollar Printed: 7/7/2004 1:12:47 PM Legal Well Name: 1E-123 Common Well Name: 1E-123 Event Name: ROT - DRILLING Report #: Start: 2 5/15/2004 Spud Date: 5/17/2004 Report Date: 5/24/2004 End: Rig & ran 7-518" Weatherford float shoe, 2 jts 7-5/8", 29.7#, L-80, BTCM casing, Weatherford float collar, 7 jts 7-5/8', 29.7#, L-80, BTCM casing, 1 jt as Window joint 7-5/8',29.7#, L-80, BTCM casing, 178 jts 7-5/8",29.7#, L-80, BTCM casing, 2 pup jts 1-10' & 1-20', 7-5/8', 29.7#, L-80, BTCM casing, ABB Vetco Gray 10-314" x 7-518" Casing hanger. Placed 7-5/8" x 10-1/2' Tandem Rise Centralizers at 1-10' above the float shoe, 1- between jt #1 & #2,1- 10' above the float collar, 1 on every collar from #3 to 18 (Excluding the Window joint #10). Placed Bowspring Centralizers on every joint from # 19 to #25. Casing ran to bottom very slowly due to the high deviation in the well ( 84.2 deg.), Did not have very much weight to reciprocate the pipe when on bottom, Land casing on hanger, UP 240K, DN 55K, Blocks 35K. Shoe @ 8041.37', Float collar @ 7,958.09', Window joint (42.57') @ 7,615.77'. . Printed: 7/7/2004 1:12:47 PM . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Kobm Deason Reference: 1E-123PB1 . ¿;¿{) f--O 7 r- r'ill BAKER HUGHES T'·_____________________________________ , , .-&Itr/$l-IIII·*ll1li1h1 I! , I _11..:",..';'...--1 I"-"'"i- t,-:".-:" :,., on .-:" .....J,!:t.' ¡;:::o.... - ~. .__'._.m....· Anchorage GEOScience Center ~ IJ.-11.) Contains the following: j 1 LD W G Compact Disc I (Includes Graphic Image files) 1 LDWG lister summary .!¡t blueline - MPR Measured Depth Log '/1 blueline - MPR TVD Log RECEIVED OCT 0 8 2004 Atæka 0tI &, Goo (.;()n~. L.ommISSKJ/ì Arltiøage LAC Job#: 680722 ::::: ;~)I PLEASE ACKNOW DGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 995]8 Direct: (907) 267-6612 FAX: (907) 267-6623 .. . on _.' -- ==':"'.,1 .... .... tr\ _~ '---OIP' ~~~----'~~...:-.--.---... ..,~ . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Denson , Reference: 1E-123 Contains the following: .", i{}lì7Ç 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blue1ine - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 680722 070 t-('-O 7 ~ . r'ill BAKER HUGHES Anchorage GEOScience Center ~ent By: Glen Ho I "I í Rece By:" u~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 Date: Sept. 10,2004 Date: 1) ~ f- RECEIVED ~rp? . VL.. L.: 200~ /}jas}m Oil & Gas Cons. CommiUfon Anchorage ~;, .,~"..,., .....~".... -,,"'". -,. · ConocóPhillips i Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-6830 July 26, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 E-123, 1 E-123PB1 and 1 E-123L 1 ~6_.2Ø4" 074 & 204-075) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 E-123, 1 E-123PB 1 and 1 E-123L 1. If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. !ð¡;~~4 Kv~f R. Thomas Kuparuk Drilling Team Leader CPAI Drilling /104tc¿:J RT/skad n ~. " r.J \ \\\ [1 \ \.J I ! \1 ¡ \ I- . STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil [2] Gas U GINJ D 2. Operator Name: WINJ D WDSPL D Plugged D Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 933' FSL, 630' FEL, Sec. 16, T11 N, R1OE, UM At Top Productive Hprizon: 644' FNL, 1141' FEL, Sec. 15, T11N, R10E, UM Total Depth: 416' FNL, 875' FEL, Sec. 10, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 r y- TPI: x- 554626 y- Total Depth: x- 554843 ' y- 18. Directional Survey: Yes [2] NoU 21. Logs Run: G RIRes/Dens/Neutron 22, CASING SIZE WT. PER FT. 62.5# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 16" 10.75" 7.625" 4.5" 5960520 · 5964255 5969764 Zone-4 Zone-4 Zone- 4 Suspended D 20AAC 25.110 Other WAGD 5. Date Comp., Susp.. or Aband.: June 16, 2004 6, Date Spudded: May 16, 2004 7. Date TD Reached: May 28,2004 8. KB Elevation (It): 28' RKB 9. Plug Back Depth (MD + TVD): 13457' MD I 3705' TVD 10. Total Depth (MD + TVD): · 13460' MD I 3705' TVD ' 11. Depth where SSSV set: none 19. Water Depth. if Offshore: N/A feet MSL CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3695' 28' 2205' 28' 8041' 28' 3574' 7744' 13459' 3522' 3705' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none. state "none"): slots in lower liner from 7886' - 12822". 13144 -13390' MD 26. Date First Production July 19, 2004 Date of Test Hours Tested 7/22/2004 9 hours Flow Tubing Casing Pressure press. 210 psi 1024 27. 24. SIZE 4.5" 25. 1b. Well Class: Development [2] Service D 12. Permit to Drill Number: Exploratory D Stratigraphic Test D 204-074 I 13. API Number. 50-029-23208-00 I 50-029-23208-70 14, Well Name and Number: 1 E-123/1 E-123PB1 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25651 & 25648 17. Land Use Permit: ALK 469 & 466 20. Thickness of Permafrost: 1530' MD HOLE SIZE AMOUNT CEMENTING RECORD PULLED Production for OIL-BBL 1182 OIL-BBL 42" 13.5" 300 sx AS I 723 sx AS III Lite. 214 sx DeepCrete 455 sx DeepCrete slotted liner 9-7/8" 6.75" TUBING RECORD DEPTH SET (MD) 6642' PACKER SET none ACID. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 24-Hour Rate -> 3082 2946 CORE DATA Test Period --> Calculated nla Submit core chips; if none, state "none". Brief description of lithology, porosity. fractures, apparent dips and presence of oil. gas or water (attach separate sheet. if necessary). PRODUCTION TEST Method of Operation (Flowing, gas lilt. etc.) Gas Lift producer - production shared with upper lateral 1 E-123L 1 GAS-MCF WATER-BBL CHOKE SIZE 1078 0 GAS-MCF W A TER-BBL ~¡afå., AU6 0 5 ~!no~ NONE Form 10-407 Revised 12/2003 A.F1PMS t1r'" r-éÒMPlE110N i :, " ·a_~~ ",BED . I ---, . ' . _J ,,"G ~ 5 .UEDf>Ñ ÁËÎ;1ERSÊ ; t. .1;-1 100% OIL GRAVITY - API (corr) IGAS-Oll RATIO 324 not available {¡~ 28. e 29. e GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-123 West Sak D 7632' 3494' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~I Randv ThO~ I Title: Signature Jf1f7~ ~¿1L~one Kuparuk Drillino Team Leader Contact: Steve McKeever @ 265-6826 7/26/0'1 Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 n \, e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/15/2004 12:00 - 13:45 1.75 MOVE DMOB MOVE Install grabber guide bowl & safety wire all bolts, Prep. rig for move. 13:45 - 15:30 1.75 MOVE MOVE MOVE Move rock washer, Boilers, Motors, Pumps, Pits, Sub complexes off 3H-10B. 15:30 - 18:15 2.75 MOVE MOVE MOVE Move Boilers, Motors, Pumps, Pits, Sub complexes from 3H Pad to 1 E Pad. Note; Camp on High line power @ 18:00 hrs. 18:15 - 19:30 1.25 MOVE POSN MOVE Spot Sub complex over hole on 1 E-123. 19:30 - 21 :00 1.50 MOVE POSN MOVE Set matts, Spot Pits, Pumps, Motors, Boilers, Rockwasher into position. 21 :00 - 23:30 2.50 MOVE MOVE MOVE Move pipe sheds from 3H Pad to 1 E Pad, Hook up steam, Air, Water and Glycol lines on rig, Work on rig acceptance list. 23:30 - 00:00 0.50 MOVE POSN MOVE Set pipe sheds into position. 5/16/2004 00:00 - 04:30 4.50 WELCTL NUND RIGUP Nipple up 21-1/4" Diverter system, Mix Spud mud 04:30 - 06:45 2.25 DRILL RIRD RIGUP Load pipe shed with BHA tools, HWDP, Drill pipe, Continue to mix spud mud. 06:45 - 11 :00 4.25 DRILL PULD RIGUP Pick up 29 jts. HWDP, Jars, 90 jts. Drill pipe & stand back in derrick. 11 :00 - 11 :30 0.50 WELCTL BOPE RIGUP Perform Diverter I Accumulator function test, Waived witness test by AOGCC John Crisp. 11 :30 - 13:45 2.25 DRILL PULD SURFAC Make up 13-1/2" Bit, 8" motor wI 1.6 deg AKO, NMDC's, Stab, MWD, XIO's, RIH w/1 stand HWDP. 13:45 - 14:15 0.50 DRILL CIRC SURFAC Tag @ 97', Fill conductor & check for leaks, Clean out to 108'. 14:15 - 15:00 0.75 DRILL DRLG SURFAC Spud well @ 14:15 hrs 5/16/04, Drill f/108' to 188'. 15:00 - 16:00 1.00 DRILL PULD SURFAC Stand back HWDP, Pick up 3 NMCSDP, Wash f/155' to 188'. 16:00 - 18:45 2.75 DRILL DRLG SURFAC Drill 13-1/2" hole f/188' to 343' (Started sliding @ 195'= KOP), SUrveys shoWIng~ AzImuttt(Possible magnétic interfe!'aIÏte, Ctösest well slot 1;7= 45') 18:45 - 20:00 1.25 DRILL TRIP SURFAC POOH to motor and recheck orientation- OK. 20:00 - 21 :30 1.50 RIGMNT RGRP SURFAC Repair top drive- Replace sheared bolts on Stand jump ram, Service top drive. 21 :30 - 22:30 1.00 DRILL TRIP SURFAC Chalk tools in hole to 343', Take check shot surveys @ 285',335' (Still magnetic int.). 22:30 - 00:00 1.50 DRILL DRLG SURFAC Drill 13-1/2" hole f/343' to 464' (Continue drilling on course to gain seperation and eliminate magnetic interferance). 5/17/2004 00:00 - 02:00 2.00 DRILL DRLG SURFAC Drill fl 464' to 641' MD / 638' TVD, AST = 1.3 hrs, ART = 0 hrs, WOB 5/20K, 550 GPM @ 1200 psi, UP 71 K, DN 67K, (Surveys showing magnetic interferance, Steering motor with chalk line). 02:00 - 02:15 0.25 DRILL CIRC SURFAC Circ hole clean. 02: 15 - 03:45 1.50 DRILL TRIP SURFAC POOH, Stand back BHA, Change out MWD tools. 03:45 - 05:15 1.50 DRILL TRIP SURFAC RIH, Take check shot surveys @ 267',357',448',537',631'. 05:15 - 07:00 1.75 DRILL TRIP SURFAC POOH to BHA. 07:00 - 10:00 3.00 WAlTON EOIP SURFAC Wait on Sperry-Sun GYRO. 10:00 - 10:30 0.50 DRILL TRIP SURFAC RIH to 267'. 10:30 -11:15 0.75 DRILL RIRD SURFAC Rig up Halliburton wire line service, Run GYRO survey. 11:15-13:00 1.75 DRILL TRIP SURFAC RIH to 641', Take GYRO surveys @ 357',447',537',627'. 13:00 - 14:15 1.25 DRILL CIRC SURFAC Circ & Rig down Halliburton wire line. 14:15 - 00:00 9.75 DRILL DRLG SURFAC Drill f/641' to 1,735' MD 11,520' TVD, AST = 7.1 hrs, ART = 0 hrs, WOB 30/35K, 600 GPM 2150 psi, UP 91K, DN 82K, ROT 87K. 5/18/2004 00:00 - 02:45 2.75 DRILL DRLG SURFAC Drill f/1, 735' to 2,103', AST = 1.0 hrs, ART = 0.8 hrs, WOB 10/30K, 50 RPM, 600 GPM 2150 psi, UP 91K, DN 82K, ROT 87K, TO on 6K15K off. 02:45 - 03:30 0.75 DRILL CIRC SURFAC Pump Hi-vis sweep & circ hole clean wI 620 gpm @ 2000 psi, 50 RPM. 03:30 - 04:15 0.75 DRILL TRIP SURFAC POOH to BHA @ 1,085' (Hole in very good shape). 04:15 - 07:45 3.50 DRILL OTHR SURFAC Stand back BHA to Motor, Drain motor & attempt to change rotor nozzle- No Good, Reset Motor AKO to 1.2 deg., RIH wI BHA. Printed: 717/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: RIH to 2,020', Precautionary wash to 2,103' (Hole in good shape). Drill f/2,103' to 3,705', AST= 1.6 hrs, ART= 5.6 hrs, WOB 15/30K, 100 RPM, 759 GPM 3100 psi, UP 119K, DN 73K, ROT 89K, TQ on 9K- 8/1 OK off. Pump Hi-vis sweep & circ hole clean, Monitor well- Static. Back ream out at drilling rate f/3,705' to 2,565'. Circ btm's up & hole clean while POOH very slow, Pumping at rate of 750 gpm @ 2800 psi, 100 RPM, Circ 2 times btm's up (Had increase of about 30% in cuttings over drilling, then cleaned up fine on 2nd btm's up). POOH on elevators f/2,400' to 890' (Worked thru tight spot f/952' to 922'- Wipe through same several times f/1002' to 890'). Stand back HWDP, Lay down Flex collars, Stab, MWD, Motor, Bit, Clear rig floor. Rig to run 10-3/4" casing, Make dummy run with Veto Gray 18-3/16"x 10-3/4" casing hanger, PJSM with all crew members. fltun 10-314" Weathdrd Float shoe, 2 its 10-3/4", 45.5#, L-80, BTC csg, Weatherford Float collar, 87 its 10-3/4",45.5#, L-80, BTC csg, Veto Gray 18-3/16"x 10-3/4" casing hanger, Ran 10-3/4"x 15-718" Bow spring centralizers as follows= 1-10' above shoe, On collar between it. #1 & #2, 1-10' below float collar, 1-20' above float collar, 1 every 30' on stop rings for 12 its., 1 on every collar on jts #12 thru #20, Total of 22 centralizers and 12 stop rings. Pump & work thru tight spot @ 960', Wash down to 1,321', Then continue to RIH to btm Ffoat shoè @3';894.60', FtóIJt COllar @ 3,610.75'. 1.00 CEMENTCIRC SURFAC Circ btm's up with Frank's fill up tool at rate of 3 bpm @ 400 psi, fùIIeip(~ csg 15'- UP 160K, DN 90K. 0.50 CEMENTPULD SURFAC Lay down Frank's fill up tool, Rig up Dowell cement head. 1.75 CEMENTCIRC SURFAC Continue to condition mud for cement, Stage rate up to 7 bpm @ 550 psi, Final mud properties 9.6 ppg, 49 vis, PV 17 YP 14, Gels 3/5, PH 8.4, Hold PJSM for cmt job. 4.25 CEMENT PUMP SURFAC Rig Dowell, Mix & pump 5 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 400 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.5 bpm @ 165 psi, Shut down and drop btm plug, Mix & pump 123sxs(513.7bb1s} lead ArctlcS4!t11l cmtmiXed at 10.7 PPft_additives at rate of 6.4 bpm @ 200 psi, Followed by 214 sxs (95.1 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg w/ additives at ... of;6... @ 340 psi, Shutdown and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/321.6 bbls 9.6 ppg mud (total of 341.6 bbls to bump plug) at rate of 7.0 bpm @ 600 to 730 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug w/1 000 psi, Floats held- OK, CIP @ 21 :48 hrs 5/19/04, Had good returns thru out job, Reciprocate csg.15' until MudPUSH at surface then pipe begM talrdng wt.. H_~~~_~_ømface. Test casing to 2500 psi for 30 min. on chart- OK. Rig down Dowell cement head, Flush riser and flow line, Rig down casing equip. Nipple down Diverter system. Nipple down Stating head. 5/18/2004 04:15 - 07:45 3.50 DRILL OTHR SURFAC 07:45 - 08:30 0.75 DRILL TRIP SURFAC 08:30 - 20:45 12.25 DRILL DRLG SURFAC 20:45 - 21 :45 1.00 DRILL CIRC SURFAC 21:45 - 23:15 1.50 DRILL TRIP SURFAC 23: 15 - 00:00 0.75 DRILL CIRC SURFAC 5/19/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC 01 :00 - 04:00 3.00 DRILL PULD SURFAC 04:00 - 06:00 2.00 CASE RURD SURFAC 06:00 - 14:30 8.50 CASE RUNC SURFAC 14:30 - 15:30 15:30 - 16:00 16:00 - 17:45 17:45 - 22:00 22:00 - 22:30 0.50 CASE MIT SURFAC 22:30 - 00:00 1.50 CEMENT RURD SURFAC 5/20/2004 00:00 - 02:30 2.50 WELCTL NUND SURFAC 02:30 - 05:00 2.50 WELCTL NUND SURFAC Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/20/2004 02:30 - 05:00 2.50 WELCTL NUND SURFAC 05:00 - 05:45 0.75 WELCTL NUND SURFAC 05:45 - 08:30 2.75 WELCTL NUND SURFAC 08:30 - 13:15 4.75 WELCTL BOPE SURFAC 13:15 - 15:00 1.75 RIGMNT RSRV SURFAC 15:00 - 17:30 2.50 DRILL PULD SURFAC 17:30 - 22:00 4.50 DRILL PULD SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 23: 15 0.25 DRILL CIRC SURFAC 23:15 - 00:00 0.75 DRILL TRIP SURFAC 5/21/2004 00:00 - 00:45 0.75 CEMENT TRIP SURFAC 00:45 - 04:00 3.25 CEMENT DSHO SURFAC 04:00 - 05:00 1.00 DRILL CIRC SURFAC 05:00 - 06:00 1.00 DRILL LOT SURFAC 06:00 - 06:45 0.75 DRILL CIRC INTRM1 06:45 - 07:45 1.00 DRILL DRLG INTRM1 07:45 - 09:30 1.75 DRILL CIRC INTRM1 09:30 - 12:00 2.50 DRILL DRLG INTRM1 12:00 - 22:30 10.50 DRILL DRLG INTRM1 22:30 - 23:00 0.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 5/22/2004 00:00 - 05:30 5.50 DRILL DRLG INTRM1 05:30 - 06:00 0.50 DRILL CIRC INTRM1 06:00 - 07:30 1.50 DRILL DRLG INTRM1 07:30 - 08:00 0.50 DRILL CIRC INTRM1 08:00 - 12:00 4.00 DRILL DRLG INTRM1 12:00 - 22:00 10.00 DRILL DRLG INTRM1 NOTE: Took 2.5 hrs to remove Vetco Gray stating head due to new design, Load shoulder ring slipped over and would not let the slip plate slip buy it, Had to remove the slips and leave the ring on the conductor. Nipple up & test Vetco Gray Well head to 5000 psi for 10 min. Nipple up BOPE. Test BOPE to 250 low and 5000 psi high, Hydrill to 250 low and 3500 high, "[est waived by AOGCC Jeff Jones. Set wear bushing. Slip & cut drilling line, Service top drive & Blocks. Pick up 75 joints 5" drill pipe from pipe shed and stand back in derrick. Pick up 9-7/8" AutoTrak BHA= Bit, AutoTrak, MAP sub, STOP sub, NM XIO, FIS, NM Stab, 3-NMCSDP, XIO, 3-HWDP, Jars, 26-HWDP, Ghost Reamer, Program & load tools, Surface test same wI 550 gpm @ 1100 psi - Weak Pulse. Pick up and single in hole wI 5" drill pipe to 2,160'. Retest AutoTrak tools wI 550 gpm @ 1450 psi- OK. Continue to Pick up and single in hole wI 5" drill pipe to 3,374'. RIH to 3,560, fill pipe. Continue RIH and tag top of Float Collar at 3,610. Drill out FC and shoe track. Drill out Float Collar at 3,692', and drill 20' of new hole to 3,725'. Sweep hole clean with 80 rpm, 150 SPM and 1,800 psi. RU and perform LOT wI 766 psi surface pressure, for an EMW of 16.0 ppg. Displace hole with clean 9.0 ppg LSND mud at 1800 psi and 150 spm. Drill 9-7/8" hole to 3,836' TMD. Circ bottoms up, and perform PWD Baseline test. Drill 9-7/8" hole with AutoTrak to 4,160' tmd. ADT= 2.0 hrs, WOB-5-15K Ib, GPM-507-635, RPM-115, Pump- 1,200 psi, Torque ON/OFF = 5-7,000 14-8,000 ft-Ib Drill 9-7/8" hole with AutoTrak to5.9ØO'trnd. ADT = 7.2 hrs, WOB-5-20K Ib, GPM-657, RPM-120, Pump- 1,975 psi, Torque ON/OFF = 11-15,000/10-12,000 ft-Ib Changedout blindeO off, st'Ieker SCt'eens with oily U¡¡rnJ sands. NOTE: Water over the Kuparuk River bridge, bridge closed. Drill ahead to 6,065' tmd ADT = 1.0 hrs. Drill 9-7/8" hole with AutoTrak: 6,065' - 6,782' tmd. WOB-5-20K Ib, GPM-655, RPM-150, Pump- 2,100 psi, Torque ONIOFF = 15-20,000/18,000 ft-Ib Change out shaker screens that wers blinded off by oily Ugnu sands. Drill ahead to 6,898' . Change out shaker screens that were blinded öff by Oily Ugnu sands. Control Drill 9-7/8" hole with AutoTrak: 6,898' - 7,245' tmd. ADT = 7.0 hrs (for tower), WOB-5-20K Ib, GPM-655, RPM-150, Pump- 2,100 psi, Torque ON/OFF = 15-20,000/18,000 ft-Ib Drill 9-7/8" hole with AutoTrak: 7,245' - 8,013' tmd. WOB-5-20K Ib, GPM-655, ECD-1 0.2-1 0.4 ppg (Calculated ECD at 7-5/8" csg shoe = 10.06 ppg), RPM-150, Pump- 2,250 psi, Torque ONIOFF = 12-19,000/16-17,000 ft-Ib ADT = 7.3 hrs (for tower) (Drilled concretions for 2hrs: 7,690-7725' Note: Held a Pad evacuation drill for all. Printed: 717/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/22/2004 12:00 - 22:00 10.00 DRILL DRLG INTRM1 22:00 - 22:15 0.25 DRILL CIRC INTRM1 Circulate out gas cut mud (max=906 units) 22:15 - 22:30 0.25 DRILL DRLG INTRM1 Drill ahead to 8,047' 22:30 - 22:45 0.25 DRILL CIRC INTRM1 Circulate, survey, downlink and re-program AutoTrak. 22:45 - 00:00 1.25 DRILL REAM INTRM1 Flow check, backream out of hole 8,047'-7,459' at 635 gpm, 150 rpm, 12-15,000 ft-Ibs of torque. Worked tight spot at 7,621'. 5/23/2004 00:00 - 01 :00 1.00 DRILL REAM INTRM1 Continue to backream from 7,459' to 7,181 '. Worked thru tight spots from 7,300' -7,181'. Well started unloading excess cuttings (3x cuttings rate over the shakers as when it was drilled). RIH to 7,645', below the first tight. 01 :00 - 01 :30 0.50 DRILL CIRC INTRM1 CBU, until returns started cleaning up. 01 :30 - 03:00 1.50 DRILL REAM INTRM1 Backream form 7,695' - 6,995' at 150 rpm and 635 GPM, wlo problems. 03:00 - 04:00 1.00 DRILL CIRC INTRM1 Pump 35 bbl of Hi-Vis I weighted sweep and circulate. (10% increase in cuttings). 04:00 - 07:15 3.25 DRILL TRIP INTRM1 Flow check - static. POOH on elevators from 6,995' - 3,653'. Hole taking proper fill. 07:15 -11:00 3.75 DRILL TRIP INTRM1 Flow check f/15 min. POOH and LD 28 stds of 5" DP, Ghost reamer, 29 Jts of HWDP, BHA. 11 :00 - 12:00 1.00 DRILL PULD INTRM1 Download MWD, LD same. 12:00 - 12:45 0.75 WELCTL OTHR INTRM1 Pull WB, set test plug. 12:45 - 13:45 1.00 WELCTL BOPE INTRM1 Change out top set of pipe rams to 7-5/8" and tested to 3,500 psi. 13:45 - 14:00 0.25 CASE OTHR INTRM1 Make Dry run with landing joint and csg hngr. 14:00 - 15:00 1.00 CASE RURD INTRM1 RU equipment for 7-518" csg. 15:00 - 20:30 5.50 CASE RUNC INTRM1 PJSM. Run casing to 3,690'. Up Wt = 127K, Dwn Wt + 69K. 20:30 - 21 :45 1.25 CASE CIRC INTRM1 Circulate casing, staging up to 5 BPM and 325 psi. 21 :45 - 22:30 0.75 CASE CIRC INTRM1 Change out sealing cup on Frank's Tool. 22:30 - 00:00 1.50 CASE RUNC INTRM1 Run casing in open hole to 5,128. Avg MU TO = 9,000 ft-Ib. 5/24/2004 00:00 - 01 :00 1.00 CASE RUNC INTRM1 Continue to run 7-5/8" casing to 5,560'. 01 :00 - 01 :45 0.75 CASE CIRC INTRM1 Break circ at 2 bpm & stage up to 6 bpm @ 500 psi. 01 :45 - 05:00 3.25 CASE RUNC INTRM1 Continue to run 7-5/8" casing, Total of 188 joints, 1-10'pup, 1-20' pup, Make up landing loint & land ~Ø,041·. 05:00 - 05:45 0.75 CASE RURD INTRM1 Lay down Frank's fill up tool, Rig up Dowell cement head. 05:45 - 07:15 1.50 CEMENTCIRC INTRM1 Break eire, Stage rate up to 6 bpm @ 550 psi, Circ & condo mud for cement. 07:15 - 10:15 3.00 CEMENT PUMP INTRM1 Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.3 bpm @ 240 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 5.5 bpm @ 220 psi, Shut down and drop btm plug, Mix & pump 456sx.s (186.4 bbls) Tail DeepCRETE cmt mixed at 12.5 ppg wI additives at rate of 6.0 bpm @ 300 psi, Shut down and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 341.7 bbls 9.0 ppg mud (total of 361.7 bbls to bump plug) at rate of 6.5 bpm @ 200 to 930 psi, Slowed rate to 3.5 bpm @ 1050 psi for last 10 bbls of displacement, Bump plug wI 1700 psi, Floats held- OK, CIP @ 10:15 hrs 5/24/04,_~ retumsthru out job, Unable to reciprocate casing due to ~~ive up anddoWA-Øraiwith 842 deg. deviation. UP 240K, DN 55K, Blocks 35K. 10:15-11:00 0.75 CASE MIT INTRM1 Test 7-5/8" casing to 3000 psi for 30 min.- OK. 11 :00 - 12:15 1.25 DRILL LOT INTRM1 Rig & pump down 7-5/8" x 10-3/4" annulas wI 30 bbls mud, Monitor well for 15 min's, Held 410 psi, 1.02 bbls back, Used 9.0 ppg mud, 760 psi= 15.6 ppg EMW. 12:15 - 13:15 1.00 CEMENTRURD INTRM1 Rig down casing tools, Cement head, Lay down landing joint. 13:15 - 14:15 1.00 WELCTL EORP INTRM1 Install FMC Gen 5 7-5/8" pack off, Test same to 5000 psi for 10 min.- Printed: 7m2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/24/2004 5/25/2004 5/26/2004 5/27/2004 OK. Change top rams to 3-112" x 6", Btm rams to 4", Set wear bushing. Rig & lay down all 5" drill pipe from derrick using mouse hole.. Change out 5" equipment to 4", Load pipe shed with Push pipe and 4" drill pipe, Pick up 9 stands push pipe. Continue to pick up Push pipe, Stand back same in derrick. PJSM, Pick up 174 jts. 4",14#, S-135, XT-39 drill pipe from pipe shed. PJSM, Slip & cut drilling line 59', Service rig. POOH & stand back 24 stands 4" Drill pipe without LO TAD's, POOH, Pick up LO TAD's on 34 stands & stand back same. Pull wear bushing, Set test plug, Test all BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, ~Jeff Jon~ waived wüness of test., Set wear bushing. Pick up 6-3/4" BHA, Bit, Turbo reamer, Motor wI 1.2 AKO, LWD/MWD/PWD, 3-NMCSDP, XO, 1-HWDP, Jars, 1-HWDP, XO, Total BHA= 255.09'). Pick up 56 stands (168 jts., 5,234.39') 4" drill pipe without LO TAD's from pipe shed, Pick up 26 stands 4" drill pipe from pipe shed with LO TAD's. 1.50 DRILL TRIP INTRM1 Continue to pick up 4"drill pipe & Lo Tad's (Total 26 stands with Lo Tad's) to 7,907'. 2.50 CEMENTDSHO INTRM1 Break eire, Tag float collar @ 7,958', Drill out float collar @ 7,958', Cmt, Shoe @ 8,041', Cmt to 8,047', Drill new hole f/8,047' to 8,067' wI 300 gpm @ 1875 psi, WOB 5/10K, RPM 50, 8/1 OK TO, UP 86K, DN 55K, ROT 83K. Circ & change over to 9.2 ppg Flo Pro mud at rate 300 gpm @ 1700 psi. Rig & periorm LOT 0115.9 ppgEMW wi 9.2 ppg mud,1254psi, 3574' TVD. Drill f/ 8,067' to 8,195' (128') AST = .50 hrs, ART = 1.0 hrs, WOB 5/10K, RPM 100, 315 gpm @ 1900 psi, UP 104K, DN 65K, ROT 82K, TO 5K onl 5K off, ECD's range f/1 0.9 to 11.2 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units. 1.00 DRILL CIRC PROD Circ btm's up & perform PWD clean hole base line tests as follows. æO~m ~~m ~~m 90 RPM= 10.6 ECD 90 RPM= 10.76 ECD 100 RPM= 11.0 ECD 100= 10.79 ECD 100 RPM= 10.86 ECD 110 RPM= 11.02 ECD 110= 10.81 ECD 110 RPM= 11.02 ECD 15.00 DRILL DRLH PROD Drill f/8,195' to 9,820' (1,625') AST= 1.1 hrs, ART= 7.6 hrs, WOB 5/14K, RPM 110/115,337 gpm @ 2100 psi, UP 109K, DN 64K, ROT 83K, TO 6K on/7K off, ECD's range f/11.2 to 11.5 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units. Noæ: At +/- 9,150' MD, Connection Q$8EIS increesedt/400 to 1740 units, Mud cut f/9.2 to 8.3 ppg, Gas eire's to +/- 50 units with ECD's. 12.00 DRILL DRLH PROD Drill f/9,820' to 10,820' (1,000') AST= 1.0 hrs, ART= 6.2 hrs, WOB 2I14K, RPM 110/115, 337 gpm @ 2400 psi, UP 109K, DN 62K, ROT 82K, TO 7K on/7K off, ECD's range f/11.2 to 11.5 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, COnnection gases f/100 to 850 units. 12.00 DRILL DRLH PROD Drill f/10,820' to 11,983' (1,163') AST= 0.8 hrs, ART= 6.7 hrs, WOB 5/14K, RPM 110/115,337 gpm @ 2650 psi, UP 117K, DN 59K, ROT 81 K, TO 9K onl 9K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 13:15 - 14:15 1.00 WELCTL EORP INTRM1 14:15 - 16:30 2.25 WELCTL EORP INTRM1 16:30 - 21:00 4.50 DRILL PULD INTRM1 21 :00 - 00:00 3.00 DRILL PULD INTRM1 00:00 - 01 :00 1.00 DRILL PULD INTRM1 01 :00 - 05:00 4.00 DRILL PULD INTRM1 05:00 - 06:30 1.50 RIGMNT RSRV INTRM1 06:30 - 10:45 4.25 DRILL PULD INTRM1 10:45 - 16:15 5.50 WELCTL BOPE INTRM1 16:15 - 18:00 1.75 DRILL PULD INTRM1 18:00 - 00:00 6.00 DRILL TRIP INTRM1 00:00 - 01 :30 01 :30 - 04:00 04:00 - 05:00 1.00 DRILL CIRC INTRM1 05:00 - 06:00 1.00 DRILL LOT INTRM1 06:00 - 08:00 2.00 DRILL DRLH PROD 08:00 - 09:00 09:00 - 00:00 00:00 - 12:00 12:00 - 00:00 Printed: 7/7/2004 1: 13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/27/2004 12:00 - 00:00 12.00 DRILL DRLH PROD ppg, Ave B~~tt1.0...ftl.>~n gasesff100to 1025 units. 5/28/2004 00:00 - 02:45 2.75 DRILL DRLH PROD Drill f/11 ,983' to 12,131' (148') AST = 0.3 hrs, ART = 1.0 hrs, WOB 5/10K, RPM 110/115, 325 gpm @ 2700 psi, UP 117K, DN 59K, ROT 81 K, TO 9K on/9K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, Connection gases f/100 to 600 units. Note} Logs Showed we drlltedootånd above sand. ~ 02:45 - 03:00 0.25 DRILL TRIP PROD BItídt.... CJUt;to1't;95O' 1251 03:00 - 06:00 3.00 DRILL DRLH PROD Time drill, Side track low side of hole f/11 ,950 to 12,131', AST = 1.0 hrs, ~ ART = 0.5 hrs. 06:00 - 12:00 6.00 DRILL DRLH PROD Drill f/12, 131' to 12,760' (810') AST = 1.0 hrs, ART = 3.0 hrs, WOB 5/10K, RPM 110/115, 325 gpm @ 2700 psi, UP 122K, DN 52K, ROT 84K, TO 10K on/10K off, ECD's range f/11.3 to 11.6 ppg, Mud wt. 9.2 ppg, Ave BGG 30 to 40 units, Connection gases f/100 to 300 units. 12:00 - 21 :30 9.50 DRILL DRLH PROD Drill f/12, 760' to 13,460' (700') AST = 1.4 hrs, ART = 4.0 hrs, WOB 517K, RPM 110/115, 325 gpm @ 2800 psi, UP 130K, DN 65K, ROT 95K, TO 9K onl 8K off, ECD's range f/11.3 to 11.8 ppg, Raise mud wt. to 9.4 ppg prior to TD, Ave BGG 30 to 40 units, Pump sweep on last connection. 21 :30 - 23:00 1.50 DRILL CIRC PROD Finish circ sweep around, Gas below 30 units, Drop rabbit, Monitor well - well showing slite flow but decreasing. 23:00 - 00:00 1.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/13,460' to 12,780', 325 gpm @ 2600 psi, 100 RPM. 5/29/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/12, 780' to 12,131', 325 gpm @ 2600 psi, 100 RPM, Hole not taking correct fill (Gain of 2 bbls- should be a loss of 12.8). 01:00-01:15 0.25 WELCTL OBSV PROD Observe well for 15 min.- gain of 2 bbls. 01 :15 - 02:00 0.75 DRILL TRIP PROD RIH to 13,460'. 02:00 - 03:00 1.00 DRILL CIRC PROD Circ btm's up at 325 gpm @ 2675 psi- (Trip gas and max gas 35 units). 03:00 - 03:15 0.25 WELCTL OBSV PROD Observe well for 15 min.- gain of 2 bbls. 03:15 - 05:00 1.75 DRILL CIRC PROD Circ and raise mud weight f/ 9.4 to 9.5 ppg, No mud loss, Gas below 20 units. 05:00 - 05:30 0.50 WELCTL OBSV PROD Observe well for 20 min.- gain of 0.7 bbls, Slight flow. 05:30 - 07:30 2.00 DRILL TRIP PROD Back ream out of hole at drilling rate f/ 13,460' to 12,131', 325 gpm @ 2600 psi, 100 RPM. 07:30 - 14:00 6.50 DRILL TRIP PROD Note: Observe well several times on way out to shoe with mild breathing{Checking flow for 10 min. with gains of 1.25 to 1.4 bbls). Hole took total 29 bbls (Over and above pipe displacement) while back reaming. 14:00 - 16:00 2.00 DRILL CIRC PROD Pump Hi-vis weighted sweep & circ hole clean- Had 200% increase in cuttings with sweep. 16:00 - 16:30 0.50 WELCTL OBSV PROD Observe well- nearly static, Pump dry job. 16:30 - 22:00 5.50 DRILL TRIP PROD POOH on elevators f/8,OOO' to 3,700', Observe well every 5 to 10 stands well is static at times and very slight flow at other times. (Calc. fill -24.9 bbls, Actual fill + 13 bbls, Total of ~7.9 bbI gain), Fill pipe and break circ with immediate circulation. 22:00 - 00:00 2.00 DRILL TRIP PROD Pump out of hole f/ 3,700' to 1,844' at 5 bpm @ 600 psi. (Calc. fill 1 0.7 bbls, Actual fill-21 bbls, Total of 10.3 bbls loss). Note: As of midnight at 1,844', Calculated fill for Drill pipe and Push pipe= 73.3 bbls, Actual fill = 73.0 bbls, 0.3 bbls difference). 5/30/2004 00:00 - 01 :30 1.50 DRILL TRIP PROD Pump out of hole f/1844' to 255' at 5 bpm @ 600 psi. (Calc. fill 9.1 bbls, Actual fill 14.0 bbls, Total of 4.9 bbls loss). 01 :30 - 03:00 1.50 DRILL PULD PROD Monitor well- Very slight flow, Stand back HWDP, Lay down 3- NMCSDP, Break bit, Drain motor. Printed: 7m2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/30/2004 03:00 - 04:00 1.00 DRILL PULD PROD Down load LWD tools & lay down same. 04:00 - 04:45 0.75 CASE RURD CMPL TN Rig to run 4-112" liner, PJSM wI all personnel. Note: Monitor well for 15 min. while rigging up, Had .68 bbl gain- Same as prior to POOH for liner. 04:45 - 09:00 4.25 CASE PULR CMPL TN Run 4-1/2" ROT Silver bullet guide shoe, 2- it Blank 4-1/2",12.6#, L-80, IBT casing, BOT Pack off bushing, XIO, 6- its, 32 spf, 2.5" x 1/8" x 4 rows, DWC Slotted casing, 8 its Blank 4-1/2",12.6#, L-80, DWC Casing, 119 its Slotted 4-1/2",12.6#, L-80, DWC casing, 2- its Blank 4-1/2",12.6#, L-80, DWC casing, Installed Weatherford 4-1/2" x 6-1/4" Spiral Glide centralizers every 30' sliding on stop collars on first slotted casing to 7-5/8" shoe. 09:00 - 15:30 6.50 CASE RURD CMPL TN Rig & run 2-7/8", 6.5# Inner string. 15:30 - 16:30 1.00 CASE PULR CMPL TN Pick up BOT Liner hanger, UP toOK, DN 73K, TO 4,500 ftllbs. 16:30 - 19:30 3.00 CASE RUNL CMPL TN RIH w/liner on drill pipe to 8,030' (7-5/8" shoe @ 8,041'), Running speed 30 to 50 ftlmin., Pipe displacement 1.0 to 1.5 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands. 19:30 - 21 :00 1.50 CASE CIRC CMPL TN Stage rate up and Circ btm's up at 3 bpm @ 950 psi, No btm's up gas, Mud wt. out 9.6+ ppg wI Vis 58, Mud wt in 9.5 ppg wI 53 Vis., After btm's up increase rate to 4 bpm @ 1130 psi, lost total 9 bbls while circ. 21 :00 - 00:00 3.00 CASE RUNL CMPL TN RIH wI liner on drill pipe to 10,550', Running speed 30 to 50 ftlmin., Pipe displacement 1.5 to 2.0 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands, Record torque every 10 stands, Pump 50 bbls at 3 bpm @ 950 psi while coming down with every 10th stand. 5/31/2004 00:00 - 03:30 3.50 CASE RUNL CMPL TN RIH wI liner on drill pipe to 13,460', Running speed 30 to 50 ftlmin., Pipe displacement 1.5 to 2.0 bbls per 5 stands (Calculated 2.6 bbls per 5 stands), Record UP & DN weights every 5 stands, Record torque every 10 stands, Pump 50 bbls at 3 bpm @ 950 psi while coming down with every 10th stand. 03:30 - 05:15 1.75 CASE CIRC CMPL TN Reciprocate pipe 15' to 20', Stage rate up to 4 bpm @ 1600 psi & Circ btm's up, UP 132K, DN 71 K, ROT 65K, 15 RPM @ 6500 ftllbs, Had a little sand back on btm's up. 05:15 - 05:45 0.50 CASE CIRC CMPL TN Flush pumps with Brine, Pressure test lines to 5000 psi. 05:45 - 08:30 2.75 CASE CIRC CMPL TN Pump Spacer, Change over outter annulus to 9.5 ppg wI 490 bbls brine at rate of 4 bpm @ 1650 psi, Reciprocate pipe 15' to 20', Observe spacer pill back to surface, then some thick oil, No sand observed. 08:30 - 08:45 0.25 CASE OTHR CMPL TN Clean Possum belly and under shakers. 08:45 - 10:30 1.75 CASE CIRC CMPL TN Circ another hole volume 490 bbls at rate of 5 bpm @ 1700 psi, No sand observed, Had small amounts of polymer and traces of oil. 10:30 - 11 :30 1.00 WELCTL OBSV CMPL TN Observe well, Gained 42 bbls. 30.5 bbls in first 30 min., 12 bbls in next 30 min. 11 :30 - 16:00 4.50 CASE CIRC CMPL TN Circ & raise weight to 9.7 ppg, Had 240 units gas on btm's up. Pumped max of 6 BPM wI 2450 psi (Did not set hanger), Had small amounts of poymer and traces of oil. 16:00 - 16:30 0.50 WELCTL OBSV CMPL TN Observe well, Gained 13.9 bbls in 30 min. 16:30 - 18:00 1.50 CASE CIRC CMPL TN Circ & displace 155 bbls clean 9.7 ppg brine in outter annulus at rate of 5 bpm @ 1750 psi. 18:00 - 19:15 1.25 CASE CIRC CMPL TN Drop ball, Circ down w/112 bbls clean brine at rate of 5 bpm @ 1750 psi, Set hanger wI 2800 psi @ 14,459', Top @ 7,748.72' 19:15 - 20:30 1.25 CASE DEOT CMPL TN Work pressure up to 3600 psi & ball sheared, Work 4 rounds left hand torque down to hanger (Working pipe each round- No torque observed) Printed: 7/7/2004 1:13:43 PM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRilLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 5/31/2004 19:15 - 20:30 1.25 CASE DEOT CMPL TN 20:30 - 22:00 1.50 CASE CIRC CMPL TN 22:00 - 22:45 0.75 WELCTLOBSV CMPL TN 22:45 - 00:00 1.25 DRILL TRIP CMPL TN 6/1/2004 00:00 - 03:30 3.50 DRILL TRIP CMPL TN 03:30 - 04:45 1.25 DRILL CIRC CMPL TN 04:45 - 05:00 0.25 WELCTL OBSV CMPL TN 05:00 - 06:45 1.75 DRILL TRIP CMPL TN 06:45 - 12:00 5.25 DRILL TRIP CMPL TN 12:00 -12:30 0.50 DRILL OBSV CMPL TN 12:30 - 15:30 3.00 DRILL PULD CMPL TN 15:30 - 20:30 5.00 DRILL TRIP CMPL TN 20:30 - 21 :00 0.50 DRILL DEOT CMPL TN 21 :00 - 22:00 1.00 DRILL TRIP CMPL TN 22:00 - 22:30 0.50 DRILL SURV CMPL TN 22:30 - 23:00 23:00 - 23:30 6/2/2004 23:30 - 00:00 00:00 - 00:30 00:30 - 00:45 00:45 - 05:15 \ E - \}ï, \-i- 05:15 - 06:15 06:15 - 07:00 07:00 - 08:15 08:15 - 10:00 10:00 - 10:15 10:15 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 15:00 15:00 - 17:00 17:00 - 19:00 19:00 - 20:00 20:00 - 00:00 and confirm release, Set liner top packer, Test annulus to 1500 psi for 10 min.- OK Pick up 20', Change over inner annulus 280 bbls, 9.7 ppg clean brine at rate of 5 bpm @ 1700 psi, Observed good amount of Flo Pro mud at shackers. Observe well, Gained 12.5 bbls in 30 min. POOH wI wash string, Hole is taking 3/4 hole fill. Continue to POOH to 7,748' (TOL), Hole fill Calculated= 33.1 bbls, Actual= 16.0 bbls, Gain 19.0 bbls, Observe well wI slight flow. Pump 30 Hi-vis sweep, Change over to 9.9 ppg brine at rate of 14.2 bpm @ 3000 psi. Had Heavy amount of thick oil on btm's up, then clean, No sand, Circ 3 btm's up, Lost 20 bbls while circ. Slight flow for 15 min. then dead. POOH to 5,717', Lay down liner running tools, Hole fill Calc.= 11.3 bbls, Actual= 27.5 bbls, 16.2 bbls over calc. PJSM, Rig & lay down 187 jts. 2-7/8" tbg. Monitor well, Clear floor, Hole tool 3 bbls. Make up Whipstock BHA, Orient & load MWD/LWD, RIH to 1013'. Surface test MWD, RIH slow to 7,095', Hole taking 1 to 3 bph over calc. displacement. Mad Pass K-13 wI LWD f/7,095' to 7,161', Showed dill pipe measurements 1.5' high. RIH to 7,702'. Break circ, Work pipe & orient to 10 deg. left of high side, Tag TOL @ 7,753', Stack out No Go @ 7,764', Top of Window @ 7,670' MD 3,503' TVD, Btm of window @ 7,682'. 0.50 DRILL DEOT CMPL TN Rig & test annulus to 1500 psi-No good. 0.50 DRILL DEOT CMPL TN Double check orientation (10 deg. Left of highside), Set trip anchor wI 20K, Toolface still 10 left, Shear mill bolt. 0.50 DRILL CIRC CMPL TN Change over to 9.5 ppg mud. 0.50 DRILL CIRC CMPL TN Fin displacing out 9.9 brine with used 9.5 ppg Flo-Pro mud, 0.25 WINDOWOTHR CMPL TN Pressure tested whipstock seal to 1,500 psi for 10 min, pressure bled down 200 psi to 1 ,300 psi in 10 min 4.50 WINDOWSTWP CMPL TN Milled window in 7 5/8" csg, top of window at 7,670', btm of window at 7,682', drilled 6 3/4" hole to 7,699' (17'), 2-7K wom, 120 rpm's, 300 gpm, 1,650 psi, rot wt 88K, up wt 108K, dn wt 70K, torque on & off btm 5K ft-Ibs Circ hi vis sweep and circ hole clean, 300 gpm at 1,650 psi Monitored well, had slight flow, circ btms up and max gas at btms up 45 units POOH 10 stds to 6,770', monitored well static POOH F/6,770' to 4,378', hole not taking calc fill Monitored well, gained 1/4 bbl in 10 min TIH F/4,378' to 7,670', raised MW in pits F/9.5 to 9.7 ppg Circ 9.7 ppg MW around, circ at 380 gpm at 2,400 psi, max gas at btms up 33 units Monitored well, well breathing slightly (1/4 bph rate) Pumped dry job and POOH to 4,378' Cont POOH from 4,378' to BHA at 1,013' POOH standing back DC's & HWDP, downloaded MWD and LD Milling assembly, upper string mill in gauge, cleared rig floor Pulled wear bushing and flushed out stack RU and tested BOPE, tested rams, valves and choke manifold to 250 1.00 WINDOWCIRC CMPL TN 0.75 WINDOWCIRC CMPL TN 1.25 WINDOwrRIP CMPL TN 1.75 WINDOwrRIP CMPL TN 0.25 WINDOWOTHR CMPL TN 1.75 WINDOwrRIP CMPL TN 0.50 WINDOWCIRC CMPL TN 0.50 WINDOWOTHR CMPL TN 2.00 WINDOwrRIP CMPL TN 2.00 WINDOwrRIP CMPL TN 2.00 WINDOWPULD CMPL TN 1.00 WELCTL OTHR CMPL TN 4.00 WELCTL BOPE CMPL TN Printed: 7n/2004 1:13:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: psi low and 5,000 psi high, tested Annular to 250 psi and 3,500 psi, RD and installed wear bushing Note: Lou Grimaldi with AOGCC witnessed 60% of test MU 6 3/4" Directional BHA #8, oriented and uploaded MWD TIH with BHA #8 to 7,660' (Top of window @ 7,670'), tested MWD at 3,525' and ck ok Slip and cut 95' of drlg line Displaced out 9.7 ppg Flo-Pro mud with new 9.0 ppg Flo-Pro Oriented BHA and RIH thru window with no pumps or problems, washed and reamed undergauge hole from 7,685' to btm at 7,699',325 gpm, 1,800 psi and 80 rpm's, string up wt 105k, dn wt 69K Circ hole and cond mud while changing out shaker screens due to new mud blinding off shakers, circ to sheared mud and began adding drill zone to help keep mud from running off shakers, changed screens from 2-210's & 1-175 t02-140's & 1-110 13.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology and directional plan, drilled from 7,699' to 9,195' MD/3,526' TVD, (1,496') ART 5.8 hrs, AST 1.7 hrs, ave 3-5K wob, 14K wob while drlg calcite stringers, 100 rpm's, 78 spm, 325 gpm, off btm pressure 1,850 psi, on btm pressure 2,050 psi, off btm torque 5K ft-Ibs, on btm 6K ft-Ibs, rot wt 83K, up wt 106K, dn wt 66K, 9.0 ppg MW, ave ECD 10.9 ppg, ave BGG 450-500 units, max conn gas 2,200 units with 9.0 ppg mud gas cut to 8.0 ppg 18.50 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 9,195' to 10,789' MD/3,562' TVD (1,594') ART 6.4 hrs, AST 4.3 hrs, ave 3-7K wob, 1 0-12K wob while drlg calcite stringers, 100-110 rpm's, 78 spm, 325 gpm, off btm pressure 2,200 psi, on btm pressure 2,400 psi, off btm torque 6K ft-Ibs, on btm 7K ft-Ibs, rot wt 80K, up wt 113K, dn wt 60K, 9.1 ppg MW, ave ECD 11.7 ppg, ave BGG 300-400 units, max conn gas 2,550 units from 9,435', 9.1 ppg mud gas cut to 7.8 ppg 2.00 DRILL TRIP PROD2 Backreamed out of hole taking check shots to verify accuracy of MWD tool, found when toolface was in 3rd quadrant of MWD tool would get innacurate azimuth reading, other quad runts checked ok, decision made to drill ahead and take survey's with tool face on high side 0.50 DRILL TRIP PROD2 TIH from 10,297' to 10,699', washed 90' to btm at 10,789' with no problems 3.00 DRILL DRLG PROD2 Drill, slide and survey from 10,789' to 11,083' MD/3,576' TVD (294'), ART .9 hrs, AST .5 hrs, 4-7K wob, 110 rpm's, 325 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm torque 8K ft-Ibs torque, on btm 8K ft-Ibs, rot wt 84K, up wt 115K, dn wt 60K, 9.1 MW, ave ECD 11.6 ppg, ave BGG 500 units, max gas 1,850 units from 10,983', gas cut mud to 8.0 ppg, drilling with 3% lubricants in mud, at 11,000' began adding 3% glycol to mud system 12.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 11,083' to 12,280' MDI 3,600' TVD (1,197') ART 5.2 hrs, AST .8 hrs, ave 2-14K wob, 80-115 rpm's, 77 spm, 325 gpm, off btm pressure 2,300 psi, on btm pressure 2,500 psi, off btm torque 7.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 120K, dn wt 50K, 9.2 ppg MW, ave ECD 11.6 ppg, ave BGG 400-500 units, max conn gas 3,400 units from 11,150',9.1 ppg mud gas cut to 8.0 ppg 12.00 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 12,280' to 13,232' MD/3,640' TVD (952') ART 4.8 hrs, AST .9 hrs, ave 2-14K wob, 115 rpm's, 77 spm, 325 gpm, off btm pressure 2,700 psi, on btm pressure 3,000 psi, off btm torque 8.5K ft-Ibs, on btm 9.5K ft-Ibs, (PU 7 6/212004 20:00 - 00:00 4.00 WELCTL BOPE CMPL TN 6/3/2004 00:00 - 03:00 3.00 DRILL PULD PROD2 03:00 - 07:15 4.25 DRILL TRIP PROD2 07:15 - 08:15 1.00 RIGMNT RSRV PROD2 08:15 - 09:15 1.00 DRILL CIRC PROD2 09:15 - 10:15 1.00 DRILL CIRC PROD2 10:15 -11:00 0.75 DRILL CIRC PROD2 11 :00 - 00:00 6/4/2004 00:00 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 6/5/2004 00:00 - 12:00 12:00 - 00:00 Printed: 71712004 1: 13:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/512004 12:00 - 00:00 12.00 DRILL DRLG PROD2 stds HWDP) rot wt 92K, up wt 133K, dn wt 63K, raised MW to 9.5 ppg to TD well per well plan, 9.5 ppg MW, ave ECD 11.9 ppg, max ECD 12.2 ppg, pumped 1 weighted hi vis sweep and had 50% increase in cuttings back from sweep, maintained mud with 3% lubricants along with 3% glycol No Gas readings after 16:00 hrs due to Totco unit crashing, lost highline power for 30 min, went onto rig power for 30 min then back to highline, ave gas before Totco unit quit, 500-600 units, ave conn gas 2,200 to 2,600 units 6/6/2004 00:00 - 02:15 2.25 DRILL DRLG PROD2 Drill, slide and survey 6 3/4" hole per geology, drilled from 13,232' to 13,345' MD/3,639' TVD (113') (T.D.), ART 1.2 hrs, AST .3 hrs, ave 2-14K wob, 115 rpm's, 77 spm, 325 gpm, off btm pressure 2,700 psi, on btm pressure 3,000 psi, off btm torque 9K ft-Ibs, on btm 10K ft-Ibs, (PU a total of 8 stds HWDP) rot wt 90K, up wt 138K, dn wt 63K, 9.5 ppg MW, ave ECD 11.9 ppg, max ECD 12.2 ppg, maintained mud with 3% lubricants along with 3% glycol No Gas readings due Totco unit down 02:15 - 03:15 1.00 DRILL CIRC PROD2 Pumped 30 bbl weighted hi vis sweep and circ till sweep was up into 7 518" csg and above window, circ at 325 gpm, 2,700 psi and 115 rpm's, monitored well and had very slight flow 03:15 - 10:30 7.25 DRILL REAM PROD2 Backreamed out of hole at drlg rate from 13,345' to 7,793'with no problems, backreamed out at 325 gpm, 2,400 psi and 115 rpm's, Pulled on elevators from 7,793' thru window at 7,682'-7,670' with no problems, POOH to 7,600' 10:30 - 13:00 2.50 DRILL CIRC PROD2 Circ hole above window and raised MW from 9.5 ppg to 9.8 ppg, circ hole at 325 gpm, 2,100 psi and 25 rpms, rot wt 75K, up wt 105K, dn wt 70K 13:00 - 13:30 0.50 DRILL OBSV PROD2 Monitored well, had slight breathing, gained .75 bbls in 30 min, dropped 1.74" rabbit on wire 13:30 - 19:30 6.00 DRILL TRIP PROD2 Pumped out of hole 10 stds to 6,633', lost 6 bbls mud over calc fill while pumping out, monitored well, had slight breathing, pumped dry job and POOH to BHA #8 to 250', Calc fill on trip out 40 bbls, actual fill 30 bbls 19:30 - 21 :00 1.50 DRILL PULD PROD2 POOH LD BHA #8, HWDP, jars, DC's, MWD & MM, cleared rig floor, retrieved rabbit at jars, SLM out no corr. 21 :00 - 21 :30 0.50 FISH PULD CMPL T2 MU BHA #9, Baker's fixed lug Whipstock retrieving tool, 1-jt 31/2" HWDP, float sub, bumper sub and oil jars 21 :30 - 00:00 2.50 FISH TRIP CMPL T2 TIH with BHA #9 with DP assembly to be used to run liner, RIH with 40 stds of 4" DP with Lo-Tads to 4,000', calc displacement 21 bbls, actual 19 bbls (To Run 60 stds of Lo-Tads) 6/7/2004 00:00 - 02:30 2.50 FISH TRIP CMPL T2 TIH with Baker Whipstock Retieving tool from 4,000' to 7,614', filled pipe, st up wt 115K, down wt 85K, lost 27 bbls mud to hole while TIH 02:30 - 02:45 0.25 FISH FISH CMPL T2 RIH and latched onto Whipstock at 7,678', pulled 190K, (75K Over St wt) sheared anchor and pulled whipstock free 02:45 - 03:45 1.00 FISH CIRC CMPL T2 Monitored well and had slight flow, circ 1.5X btms up at 250 gpm at 1,100 psi, max gas at btms up 40 units, lost 23 bbls mud to hole wlcirc, 50 bbls total while TIH & Circ 03:45 - 04:00 0.25 FISH OTHR CMPL T2 Monitored well and had slight flow, gained less than 1/4 bbl 04:00 - 12:00 8.00 FISH TRIP CMPL T2 POOH with whipstock from 7,668' to 2,769', POOH alternating with and with out pumps on due to swabbing, after 14 stds out, rotated DP and whipstock and well would take fluid, Began POOH rotating 4 stds without pumping & pumping and rotaing the 5 std out otwell, hole still not taking calc fill, began pulling 2 stds wIno pump and pumping 1 std Printed: 7/7/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/7/2004 04:00 - 12:00 8.00 FISH TRIP CMPL T2 out with hole taking some fluid and no signs of any gas 12:00 - 13:30 1.50 FISH TRIP CMPL T2 Pumped out of hole every stand from 2,769' to 1,200', hole took 18 bbls while pumping out of hole 13:30 - 14:30 1.00 FISH TRIP CMPL T2 Monitored well and had slight flow, cont to pump out of hole from 1,200' to 930' when BGG began to incr~ while pumping out at 930' BGG increased to 4,923 units, max gas on Totco unit, 9.8 MW gas cut to 7.0 ppg 14:30 - 17:00 2.50 FISH CIRC CMPL T2 Circ hole monitoring gas, gas would increase to 4,923 units then drop down, while moving pipe gas would increase again dropping back out, initial circ at 270 gpm at 400 psi and staged up to 340 gpm at 525 psi with 50K st wt 17:00 - 00:00 7.00 FISH TRIP CMPL T2 Staged into hole from 930' to 3,056', began puming down singles circ btms up after each stand, would max out Totco unit with 4,923 units gas back at btms up with 9.8 ppg mud gas cut to 7.0 ppg, increased MW to 9.9 ppg while pumping in hole, after 5 stds began staging in, would run 1 std wIno pump, pumping 2nd stand down, would pump down at 210 gpm at 200 psi and circ btms up at 340 gpm with initial pressure of 550 psi, at 3,056' at 340 gpm had 750 psi, increased running in hole 3 stds with no pump and pumping 4th std down and btms up gas was down to 3,500 units max and dropping out within 5 min's, 9.9 ppg MW gas cuts ranging from 7.0 ppg with 4,923 units gas to 8.4 ppg with 2,700 units gas, string up wt 64K, dn wt 60K, lost 31 bbls mud to hole while RIH and circ btms up to 3,056', Mud report showed in last 24 hrs had a total loss of 39 bbls to hole 6/8/2004 00:00 - 07:00 7.00 FISH TRIP CMPL T2 Cont to stage in hole with whipstock retrieving tool from 3,056' to 7,610', staged in RIH 3 stds W/O pumping then pumping 4th std down, Circ btms up each time, increased stages to RIH 8 stds and pumping 9th std down, circ btms up at 340 gpm, initial circ pressure at 3,056', 750 psi, final circ pressure from 6,885', 1,400 psi, ave max gas at btms up was 2,700 units gas 07:00 - 07:45 0.75 FISH CIRC CMPL T2 Circ btms up at 7,610', circ at 340 gpm at 1,800 psi, max gas at btms up 1,650 units, st wt up 116K, dn wt 85K, 9.9 ppg MW gas cut to 9.0 ppg at btms up, lost approx 75 bbls mud while staging in hole & CBU 07:45 - 08:00 0.25 FISH FISH CMPL T2 RIH with retrieving tool and saw seal assembly from whipstock assembly enter top of liner, set down with 5K st wt and found whipstock to still be latched onto retrieving tool, PU out of seal assembly 08:00 - 08:30 0.50 FISH OTHR CMPL T2 Monitor well, had slight flow with no measurable gain in trip tank 08:30 - 10:00 1.50 FISH OTHR CMPL T2 Transfer 9.9 brine from tank farm to mud pits, cont. to monitor well with slight flow and no measurable gain in trip tank 10:00 -11:00 1.00 FISH CIRC CMPL T2 Displaced out 9.9 ppg mud in well over to 9.9 ppg brine, circ at 380 gpm at 2,350 psi 11 :00 - 11 :30 0.50 FISH OTHR CMPL T2 Monitor well, had slight flow with no measurable gain in trip tank 11 :30 - 17:30 6.00 FISH TRIP CMPL T2 POOH with whipstock to BHA #9 at 61', no problems POOH, calc fill on trip out, 51 bbls actual fill 49 bbls 17:30 - 19:00 1.50 FISH PULD CMPL T2 POOH LD whipstock retrieving assembly and whipstock, cleared rig floor 19:00 - 19:30 0.50 CASE RURD CMPL T2 RU to run 4 1/2" liner, held PJSM on running liner, monitored well-static 19:30 - 00:00 4.50 CASE PULR CMPL T2 PU & ran 41/2" liner to 4,717', MU 31/2" guide shoe (no float), 1 bent jt of 31/2",9.2 #, L-80 IBT-M tbg, XO to 41/2" DWC-Csg, 1 blank jt of 4 1/2",12.6#, L-80 csg, cont RIH with slotted 41/2" liner to 4,717', PU wt 65K, DN wt 57K 6/9/2004 00:00 - 01 :00 1.00 CASE PULR CMPL T2 Fin PU & RIH with 4 1/2" Liner to 5,634', Ran a total of, 1- bent it of 3 1/2" tbg, 3 blank its and 132 slotted its of 41/2" 12.6#, L-80 DCW-C, Printed: 717/2004 1:13:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/912004 00:00 - 01 :00 1.00 CASE PULR CMPL T2 Ran 17241/2" x 61/2" Spiralguides with 127 stop rings, 1 cent/every 30', recorded up and down weights every 10 jts after jt #50, calc liner displacement 25 bbls, actual displacement 20 bbls, st up wt 69K, dn wt 54K 01 :00 - 08:00 7.00 CASE PUTB CMPL T2 RU and ran 186 jts of 2 7/8" 6.5# Hydril 511 inner wash string, wash string up wt 60K, dn wt 43K 08:00 - 08:30 0.50 CASE PULR CMPL T2 MU Baker 7 518" x 41/2" B-1 flanged hook liner hanger, st wt 90K up, 68K down with 35K block weight 08:30 - 09:00 0.50 CASE RURD CMPL T2 RD Doyon's liner running tools 09:00 - 10:45 1.75 CASE RUNL CMPL T2 RIH with liner on 4" DP to 7,663', recorded up & down weights every 5 stds, st wt with 9.9 ppg brine, 115K up, 85K dn 10:45 - 13:00 2.25 CASE CIRC CMPL T2 Displaced out 9.9 brine in hole back to 9.9 ppg mud, circ at 3 bpm at 800 psi, st wt with 9.9 ppg mud, 103K up, 70K down 13:00 - 18:00 5.00 CASE RUNL CMPL T2 Oriented liner and after 2nd attempt, entered lateral with liner, RIH with liner to 13,327' with no problems, recorded up & down weights every 5 stds, calc displacement from window 13 bbls, actual 16 bbls 18:00 - 18:30 0.50 CASE OTHR CMPL T2 Oriented and hooked liner hanger at btm of window at 7,682',slacked off 30K on hanger, landed liner with shoe at 13,327' and top of liner at 7,666', 18:30 - 19:30 1.00 CASE OTHR CMPL T2 Finished transfering 9.8 ppg brine to mud pits, transfer was delayed due to injection well going down and shortage of vac trucks 19:30 - 00:00 4.50 CASE CIRC CMPL T2 Pumped 35 bbl hi vis spacer and displaced out 9.9 ppg mud in outer liner annulus to 9.8 brine, max gas 2,750 units, BGG dropped down to less than 150 units, circ out spacer, shut down and cleaned out under shakers, cont to circ hole with clean 9.8 brine, circ at 4.75 bpm at 1,975 psi NOTES: Recieved 48 hr waiver on BOP test from John Crisp W/AOGCC, Injection well 1 E-34 pressured up after water flush, decision made to quit using as an injection well, Little Red freeze protected well with 85 bbls diesel 6/10/2004 00:00 - 01 :00 1.00 CASE CIRC CMPL T2 Fin circ outer liner liner annulus with 9.8 ppg brine, circ at 4 3/4 bpm at 1,975 psi 01 :00 - 01 :45 0.75 CASE CIRC CMPL T2 Dropped 29/32" ball and pumped ball down to seat, initial rate 3 bpm at 700 psi, slowed to 2 bpm at 400 psi, with ball on seat pressured up to 3,300 psi to release running tool. 01 :45 - 02:00 0.25 CASE DEQT CMPL T2 PU on string to 135K and running tool was released, pressured up to 4,100 psi and blew ball seat, st wt 125K, slacked of into top of liner 02:00 - 04:00 2.00 CASE CIRC CMPL T2 Circ 1.5x hole volume at 7.5 bpm at 3,500 psi, then spotted clean brine in outer liner annulus, didn't see any change in returns from higher rate 04:00 - 07:00 3.00 CASE CIRC CMPL T2 PU out of liner, LD 1-jt of 4" DP, pumped 35 bbl high vis spacer and circ out of hole at 7.5 bpm at 3,500 psi, had additional 35 bbls interface from sweep, cont to circ 1.5X hole volume at 7.5 bpm then spotted clean brine in liner 07:00 - 07:15 0.25 CASE OTHR CMPL T2 Monitored well and had slight flow, no measurable gain in trip tank 07:15 - 18:00 10.75 DRILL TRIP CMPL T2 POOH LD 4" HWDP and 4" DP to 2 7/8" Inner wash string, LD 27 jts of 4" HWDP, 213 jts of 4" DP and 60 Lo-Tads, monitored well at TOL and well was static, monitored well several times WILD DP and well was static 18:00 - 18:30 0.50 DRILL PULD CMPL T2 LD Baker running tool and cleared rig floor 18:30 - 23:00 4.50 CASE PUTB CMPL T2 RU and POOH LD 186 jts of 2 7/8" Hydril 511 inner wash string 23:00 - 00:00 1.00 CMPL TN RURD CMPL T2 Pulled wear bushing and RU Doyon's tubing handling tools 6/11/2004 00:00 - 00:15 0.25 CMPL TN SFTY CMPL T2 Pre Job Safety meeting with crew and all contractors 00: 15 - 06:00 5.75 CMPLTN RUNT CMPL T2 Run Completion - Ran 212 jts 4.5" 12.6# L-80 IBTM mod wI special Printed: 7/7/2004 1:13:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/15/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: Group: 6/11/2004 00: 15 - 06:00 5.75 CMPL TN RUNT CMPL T2 06:00 - 07:15 1.25 CMPL TN RUNT CMPL T2 07:15 - 07:30 0.25 CMPL TN RURD CMPL T2 07:30 - 10:00 2.50 CMPL TN RURD CMPL T2 10:00 - 10:45 0.75 CMPL TN RURD CMPL T2 10:45 - 12:00 1.25 CMPL TN RURD CMPL T2 12:00 - 13:30 1.50 CMPL TN RURD CMPL T2 13:30 - 14:15 0.75 CMPL TN RURD CMPL T2 14:15-21:30 7.25 DRILL PULD CMPL T2 21 :30 - 00:00 2.50 DRILL PULD CMPL T2 clearance coupling 4.920" coupling - Up wt 80K, Dn wt 56K, Bk wt 35K - 9.8 ppg brine in hole M/U hanger & landing jt - Install blank penatrator thru hanger - Land tbg @ 6605 - RILDS - ABB Vetco rep James Lott Test upper and lower hanger seals to 5000 psi for 10 min - "OK" UD Landing joint - Set BPV Remove rams from BOPs - Flush out BOP body's for metal from milling NID BOPs - Set back on stump N/U Tree Con't N/U Tree - Pull BPV - Set TWC - Test tree 250/5000 psi f/10 min "OK"- Pull TWC and set BPV R/D all tbg equipment and clear from floor - RIU to UD DP UD 7500' DP from derrick using mouse hole C/O saver sub to 41/2 IF - C/O to 5" TD handling tools Rig released 23:59 hrs 6/11/04 ** Note*** 10.750" X 7.625" annulus was tested for annular injection. LOP @ 730 psi - Ann was flushed with 250 bbls water - Freeze protected wi 75.5 bbls diesel to 1902' TVD Printed: 717/2004 1:13:43 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-123 1 E-123 COMPLETION n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 6/13/2004 6/11/2004 Spud Date: 5/17/2004 End: 6/16/2004 Group: 6/13/2004 04:00 - 08:30 4.50 MOVE MOVE MOVE Prepare Rig for move. Lowered Derrick. RD Hand-Y-Berm, RD Sub, Pipe Shed, & Motor Complex. Trucks arrived and hooked up prep to move to 1 E-123. 08:30 - 11 :00 2.50 MOVE MOVE MOVE Move rig and camp from 1 L pad to 1 E pad. 11 :00 - 16:00 5.00 MOVE RURD MOVE Spot camp and connect gen. and communications satelite. RU Hand-Y-Berm around well and spot sub. RU pipe shed and motor complex. Raise derrick and scope up. Held Pre-Job meeting with Night crew. 16:00 - 19:00 3.00 MOVE RURD MOVE Complete all hookups inside rig. Accept Rig @ 1700 hrs. Hook up Rig pump to circulate with tree still on. 19:00 - 19:30 0.50 WELCTL NUND CMPL T2 Removed BPV 19:30 - 20:30 1.00 WELCTL CIRC CMPL T2 Load Pits wI 9.8# brine. Prepare to circulate hole. 20:30 - 22:15 1.75 WELCTLCIRC CMPL T2 Circulate hole wI 9.8# heavy. Pumping down the tubing and taking retums from IA. Pump Rate @ 4 BPM pump pressure @ 250 psi. Circulated 330 bbls lost app: 8 bbls of fluid during circulation. Talked wI AOGCC inspector John Crisp @ 20:45 and he waived the witness of BOP Test. 22:15 - 23:15 1.00 WELCTL OBSV CMPL T2 Monitored Hole. U-tubed from the IA to the tubing for awhile. Allowed well to equalize and monitored hole for returns. 23:15 - 23:45 0.50 WELCTL NUND CMPL T2 Drained tree and Montiored well further. Well is dead. 23:45 - 00:00 0.25 WELCTL EQRP CMPL T2 Installed BPV and Prepare to ND Tree. 6/14/2004 00:00 - 01 :00 1.00 WELCTL NUND CMPL T2 ND Tree 01 :00 - 04:00 3.00 WELCTL NUND CMPL T2 NU BOPE, discovered that between the double gate of the stack and the Hanger there would not be enough room for the Vetco Plug off tool and also the riser would have to be extended, requiring a welder. Called out for a 2' spacer spool (mud cross) to raise double gate and alleviate all problems. Continued NU BOPE. 04:00 - 05:30 1.50 WELCTL NUND CMPL T2 Spacer Spool on location. Vetco Gray Rep went ahead and installed Plug off tool on Hanger. Continued NU BOPE 05:30 - 06:00 0.50 WELCTL SFTY CMPL T2 Held Pre-completion Mtg with the day crew. 06:00 - 15:00 9.00 WELCTL NUND CMPL T2 Continued to NU BOPE. 15:00 - 18:00 3.00 WELCTL BOPE CMPL T2 As stated on yesterdays report AOGCC Inspector John Crisp waived the witness on the BOP Test.Talked with him on 06/13/04 @ 20:45. Function test BOPE. Attempt to test BOP no luck yet. Blinds Tested OK to 3500 psi. Unable to get pipe rams to test. 18:00 - 20:00 2.00 WELCTL BOPE CMPL T2 The Test joint is at to much of an angle, because of the way the hanger is offset to one side. Pulled test joint and it was scarred from the pipe rams. Installed Test joint with donut and Tested pipe rams to 3500 psi. 20:00 - 21 :00 1.00 WELCTL BOPE CMPL T2 Pulled Test joint & donut. Pulled out plug off tool. Confirmed well is still dead. Pulled BPV. Installed 2-way check. Install test joint. Test annular to 3500 psi. 21 :00 - 22:00 1.00 WELCTL BOPE CMPL T2 Pulled test joint. Confirmed well is dead. Pulled 2-way check. Test accumulators and dart valve. BOPE Test completed. 22:00 - 22: 15 0.25 CMPL TN SFTY CMPL T2 Held pre-job mtg. 22:15 - 23:00 0.75 CMPLTN TRIP CMPL T2 Pulled Hanger to the Floor. Up Wt = 58k. Laid down hanger and 1 st full joint of pipe in the pipe shed. Fit test Penetrator in Hgr (good fit). Pull 1 st full stand and rack back in derrick. 23:00 - 23:45 0.75 CMPL TN CIRC CMPL T2 Fill hole, hole is out of balance. Mixed up a 15 bbl dry job and circulated same down tbg. 23:45 - 00:00 0.25 CMPL TN TRIP CMPL T2 Able to pull dry pipe and circulate over the top of the hole keeping hole full. 5 stands racked back in derrick. Continued tripping pipe OOH. 6/15/2004 00:00 - 05:00 5.00 CMPL TN TRIP CMPL T2 Tripped OOH Racked back all tubing 05:00 - 07:00 2.00 CMPL TN PULD CMPL T2 Set up Centrilift Equipment and begin bringing ESP components to the Printed: 717/2004 1 :04:03 PM e - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-123 1 E-123 COMPLETION n1334@ppco.com Doyon 141 Start: 6/13/2004 Rig Release: 6/11/2004 Rig Number: Spud Date: 5/17/2004 End: 6/16/2004 Group: floor. Made up Centralizer, Press & Temp Sensor, Motor, Seals, TTC, & X-over. Verified Oil Fill on the Motor, tightness of all plugs, and Free rotation of Motor components. Connect ESP cable to Motor. Begin adding flat cable protectors and bands for completion proceedures. Test cable integrity. Continue to RIH. Having problems getting stand number 6 to torque up. Change out coupling. No good. Prep to change out bottom joint on stand number 6. Changed out joint and continued into hole. At stand number 9 cable dropped into a gap at the airslip guide bolt which subsequently compromised the cable. shut down for a splice. Splice ESP cable. Held Pre-job meeting went over the running ovf completion with ESP & cable. Removed roller from guide bolt on the air slip (this is what caused the cut in the cable). Began running ESP completion again. Testing ESP cable every 1000'. Continue running new ESP completion. Checking ESP cable every 1000'. Hole fill is very stable losing about 1/4 BPH brine wt @ 9.8#. Pick up hanger and begin final splice after spacing out cable length. Count bands, protectrolizers, and cannon clamps on location for accountability. Meg test passed. Landed Hgr. Final Up Wt = 72k and Down Wt 35k. RILDS. Pressure tested upper and lower hanger seals --- passed--. Back pressure valve set. Begin to nipple down the BOPE. Wash pits prep for rig move. Check ESP cable after BOP removed and it checked out good. NU tree. Checked ESP cable and it is good. PresslTemp Gauge reading 1837 psi @ 65.3 degrees. 2.00 CMPL TN SEQT CMPL T2 Pressure tested Pack ofts to 5000 psi. Pulled BPV and install 2-way check. Pressure test Tree to 5000 psi. Check ESP cable again and it checked out. 2.00 CMPL TN RURD CMPL T2 Make up Actuators to the Tree. Release Rig @ 22:00 hrs. 6/1512004 05:00 - 07:00 2.00 CMPL TN PULD CMPL T2 07:00 - 10:30 3.50 CMPL TN PULD CMPL T2 10:30 - 13:30 3.00 CMPL TN PULD CMPL T2 13:30 - 14:00 0.50 CMPL TN RUNT CMPL T2 14:00 - 15:30 1.50 CMPL TN RUNT CMPL T2 15:30 - 17:30 2.00 CMPL TN RUNT CMPL T2 17:30 - 20:30 3.00 CMPL TN RUNT CMPL T2 20:30 - 20:45 0.25 CMPL TN SFTY CMPL T2 20:45 - 00:00 3.25 CMPL TN RUNT CMPL T2 6/16/2004 00:00 - 08:00 8.00 CMPL TN RUNT CMPL T2 08:00 - 12:08 4.13 CMPL TN RURD CMPL T2 12:08 - 13:00 0.87 CMPL TN SEQT CMPL T2 13:00 - 18:00 5.00 CMPL TN NUND CMPL T2 18:00 - 20:00 20:00 - 22:00 Printed: 7/7/2004 1 :04:03 PM Cortocri'Phillips ConocoPhillips Ala! Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo_23 PB1 Well path: GSS<0-532'>MWDw/Sag & Mag<561-12132'> Date Printed: 21-Jun-2004 Ì' 0'-'1-07'1 .i. 8Ifal.s INTEQ "'V~~':'le Name 123 PB1 I Created 117 -May-2004 Name 123 18 10.4906 W149 35 45.2000 Field Name Kuparuk River Unit I EàstinQ 487754.6208 I NorthinQ 5948985.8206 I Coord SyStem Name ·1 North Alianment · AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3,65 degrees Bottom hole distance is 9319.28 Feet on azimuth 32.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 0.1'\\. ~(\\)\-- Cor1occiPt,illips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellbo.23 PB1 Wellpath: GSS<0-532'>MWDw/Sag & Mag<561-12132'> Date Printed: 21-Jun-2004 .1. aw_ INTEQ WeUpath(Grid} Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionlftl 0,00 0.00 0.00 0.00 O.OON O.OOE 0.00 0,00 549889.87 5960519.63 108.00 0.00 0.00 108.00 O,OON O.OOE 0.00 0.00 549889.87 5960519.63 171.00 0.50 100.00 171.00 O,05S 0.27E 0.79 -0.03 549890.14 5960519,58 261.00 2.50 124.00 260,96 1.21S 2,29E 2.28 -1,07 549892.16 5960518.43 351,00 3.25 128,00 350.85 3.88S 5.92E 0,86 -3.50 549895.82 5960515.79 441.00 5.75 125.00 440.57 8.04S 11.63E 2.79 -7.28 549901.55 5960511.67 532.00 11.00 128.00 530.56 16.00S 22.21 E 5.79 -14.56 549912.18 5960503.77 561.33 11.88 133.04 559.31 19.79S 26.62E 4,54 -18.05 549916.62 5960500.02 653.25 11.83 135.06 649.27 32.91S 40.19E 0.45 -30.29 549930,28 5960486,99 741.74 9.43 120.09 736,25 42,97S 52.88E 4.11 -39.52 549943.03 5960477.01 834.62 10,67 87.97 827.78 46.49S 68.06E 6.10 -42,06 549958.24 5960473.60 925.83 16.44 80.46 916.42 44.05S 89.25E 6,60 -38.27 549979.40 5960476,18 1014.61 20.05 73.39 1000.73 37.61S 116,24E 4.76 -30,13 550006.34 5960482.80 1106.56 25.56 65.84 1085.48 24,97S 149.47E 6.77 -15.40 550039.49 5960495.65 1201.72 32.04 62.88 1168.83 5.04S 190.72E 6,97 7.12 550080.60 5960515.85 1294.42 36.83 61.83 1245.26 19.30N 237.12E 5.21 34.36 550126,83 5960540.50 1386.17 41,61 62.02 1316,32 46.59N 288,30E 5.21 64.86 550177.82 5960568.13 1479,37 49.45 61,85 1381,56 77.86N 346.94E 8.41 99,80 550236.25 5960599,78 1570,56 56.83 60.96 1436.22 112.78N 410.94E 8,13 138.73 550300,01 5960635.12 1664.77 59.43 60.10 1485.96 152.14N 480.58E 2.87 182.45 550369.39 5960674.95 1757.40 63.51 59.30 1530.20 193.20N 550,83E 4.47 227.90 550439.35 5960716.47 1850.11 68.60 58.96 1567.81 236.67N 623.53E 5.50 275,90 550511.75 5960760.41 1942,84 75,37 62,83 1596.48 279.48N 700,54E 8.31 323.53 550588.47 5960803.72 2036.38 73.10 63,26 1621.90 320,28N 780,78E 2.47 369.36 550668.43 5960845.06 2135.43 70,92 62.58 1652.48 363,16N 864,65E 2.30 417.50 550752.01 5960888.49 2228.64 69.45 62.59 1684.08 403,54N 942.50E 1.58 462,75 550829.57 5960929.38 2322,02 68.53 62.45 1717,56 443.76N 1019,83E 1.00 507,82 550906.63 5960970.11 2414.07 68.09 61.83 1751.58 483.73N 1095.45E 0.79 552.52 550981,97 5961010.58 2506.77 64.84 61.70 1788.59 523.93N 1170.32E 3.51 597.41 551056,56 5961051.27 2599.39 65.27 61.87 1827.65 563.63N 1244.32E 0.49 641.75 551130,29 5961091.46 2692.63 65.99 64,01 1866.13 602.27N 1319,95E 2.23 685,12 551205.66 5961130.59 2784.99 69,94 64.20 1900.78 639.65N 1396.95E 4.28 727.33 551282.40 5961168.47 2877,87 71.12 63.53 1931,73 678.22N 1475,56E 1.44 770,83 551360.75 5961207.56 2970.53 70.65 63.90 1962.08 716.99N 1554.06E 0,63 814.52 551438.98 5961246.85 3062,50 70.20 64,30 1992,89 754,84N 1632.01E 0.64 857.26 551516.67 5961285.22 3156.65 69.00 64.81 2025.71 792.76N 1711.69E 1,37 900.17 551596.09 5961323.66 3249.77 70.17 63.89 2058.19 830.53N 1790.36E 1.56 942.89 551674.50 5961361.95 3343.09 71.01 63,24 2089.20 869,72N 1869,17E 1.11 987,01 551753.04 5961401.65 3434.43 69.58 63.70 2120.00 908.13N 1946.11E 1.64 1030.24 551829,71 5961440.57 3527.43 70.33 64.46 2151.88 946.32N 2024.68E 1.11 1073,36 551908.02 5961479,27 3597.07 71,37 65.01 2174.72 974.39N 2084.18E 1,67 1105.17 551967.32 5961507.74 3637,06 71.43 64.98 2187.47 990.41 N 2118,53E 0.17 1123.34 552001.56 5961523.99 3800.54 67.00 67,11 2245.48 1052.49N 2258.14E 2.97 1194.18 552140.75 5961586.98 3893.30 69.58 67,25 2279.79 1085,91N 2337.57E 2.78 1232.60 552219.94 5961620.93 3984,19 71.56 69.50 2310.03 1117.48N 2417.24E 3,19 1269.18 552299.40 5961653.03 4079.63 71.89 69.01 2339.95 1149.58N 2501.99E 0.60 1306,62 552383,93 5961685.69 4170.06 71.53 68.82 2368.33 1180.47N 2582.10E 0.45 1342,54 552463,82 5961717.10 4263.23 71,86 68.23 2397.60 1212.86N 2664.42E 0.70 1380.11 552545.91 5961750.03 4357,12 71,33 68.34 2427.24 1245.82N 2747.18E 0.58 1418.27 552628.45 5961783.54 4449.83 71.82 65,66 2456.55 1280.18N 2828.14E 2.79 1457.73 552709.17 5961818.44 4536.51 71.79 64,03 2483.61 1315,18N 2902,67E 1.79 1497.40 552783.46 5961853,93 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3,65 degrees Bottom hole distance is 9319.28 Feet on azimuth 32.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~illips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellbo"23 PB1 Wellpath: GSS<0-532'>MWDw/Sag & Mag<561-12132'> Date Printed: 21-Jun-2004 rea. ..,. INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] I TVD[ft] station Station Dogleg Seven, Vertical Easting Northing Position(Y) Position(X) Sectionrftl 4630.70 71,14 64.67 . 2513.56 1353.84N 2983.17E 0,94 1541,11 552863.69 5961893.12 4726.24 71.47 63.64 2544.18 1393.29N 3064.62E 1.08 1585.67 552944.87 5961933.10 4820.78 71.70 63,14 2574.05 1433.47N 3144.82E 0.56 1630.87 553024,79 5961973,81 4914.58 71.40 63,58 2603.73 1473,37N 3224.35E 0.55 1675.76 553104.05 5962014.23 5010,21 71.43 64,17 2634.21 1513,28N 3305.73E 0.59 1720.77 553185.15 5962054.68 5100.66 71.45 64.04 2663,00 1550.73N 3382.87E 0.14 1763,05 553262.03 5962092.63 5193.04 72.28 62.17 2691.76 1590.44N 3461.16E 2.12 1807.67 553340.05 5962132.86 5286.82 72.72 59.87 2719.96 1633.77N 3539.39E 2.39 1855.90 553417,98 5962176.71 5378.91 71.60 56.38 2748.18 1680.05N 3613.82E 3.81 1906.82 553492.10 5962223.47 5471,55 70.91 53.24 2777.96 1730,59N 3685.51 E 3.29 1961,83 553563.44 5962274.48 5562.73 70,62 50.67 2808.00 1783.64N 3753.30E 2.68 2019,09 553630.87 5962327.98 5658.50 70.76 49.98 2839,67 1841.34N 3822,86E 0,70 2081.11 553700.05 5962386.13 5750.69 70.56 49,31 2870.20 1897.67N 3889.15E 0.72 2141.54 553765,95 5962442.89 5844.00 71.01 45.85 2900.92 1957,10N 3954.18E 3.53 2204,99 553830.58 5962502.75 5935.64 70.27 42.92 2931,30 2018.87N 4014.66E 3.12 2270.49 553890,63 5962564.91 6028.09 69.12 40.20 2963,39 2083.74N 4072,17E 3.03 2338,89 553947.71 5962630.15 6121,56 69.25 37,91 2996.61 2151,58N 4127.22E 2.29 2410,10 554002.30 5962698.35 6214.59 69.31 37.56 3029.52 2220.39N 4180.47E 0.36 2482,16 554055.09 5962767.51 6307.74 69.29 36.75 3062.45 2289.84N 4233,10E 0,81 2554,82 554107.25 5962837.30 6400.41 69.29 37.84 3095.22 2358.80N 4285.62E 1.10 2626.98 554159.31 5962906.60 6493,21 68.92 38.41 3128.32 2427.00N 4339.14E 0.70 2698.46 554212.37 5962975.14 6585,62 68.89 39.19 3161.58 2494.19N 4393.17E 0.79 2768.95 554265.94 5963042.69 6677.13 69.16 37,91 3194.34 2561,01N 4446.41E 1.34 2839.03 554318.74 5963109.86 6772,14 70,86 31,96 3226.84 2634,18N 4497.49E 6.15 2915.31 554369.33 5963183.35 6864.06 71.76 29,59 3256.30 2708,99N 4542.04E 2.63 2992.80 554413.37 5963258.45 6957.16 71.60 25.41 3285.58 2787,36N 4582.84E 4.27 3073.61 554453,64 5963337,08 7049.29 70.72 22,86 3315.33 2866,92N 4618.49E 2.79 3155.28 554488,76 5963416.87 7142.22 71,72 22.10 3345.25 2948.22N 4652.13E 1,33 3238,55 554521.86 5963498.38 7235.20 70.98 17.24 3375,00 3031.14N 4681.78E 5.02 3323.20 554550.96 5963581.49 7327.93 71.14 11.44 3405.12 3116.07N 4703.49E 5.92 3409,34 554572.10 5963666.56 7421,17 72.02 7,36 3434.59 3203,33N 4717.93E 4.26 3497.34 554585.95 5963753,90 7514,11 73.43 4,87 3462.20 3291.56N 4727.37E 2.97 3585.99 554594.81 5963842,18 7606.88 75.12 4.93 3487.34 3380.53N 4735.00E 1.82 3675,27 554601.85 5963931.19 7699.66 75.22 5.19 3511.08 3469.87N 4742,91E 0,29 3764.93 554609.17 5964020.57 7793.30 77.08 4.04 3533.50 3560.49N 4750.22E 2.32 3855,83 554615.87 5964111.23 7885.55 79.18 4.08 3552.47 3650.53N 4756,61E 2.28 3946.10 554621.67 5964201.30 7978.47 82.63 4,95 3567.16 3741.99N 4763.84E 3.83 4037.82 554628.28 5964292,79 8009.32 84.20 3.80 3570.70 3772,54N 4766.17E 6.29 4068.47 554630.42 5964323.36 8045.73 84.25 3.20 3574.36 3808.70N 4768,39E 1,65 4104.69 554632.39 5964359.53 8136.65 90.80 3.19 3578.28 3899.34N 4773.44E 7.20 4195.47 554636.85 5964450.19 8239,82 92.15 2.35 3575,63 4002.35N 4778.43E 1.54 4298.60 554641.15 5964553.23 8335.78 91.57 1,50 3572.51 4098.21N 4781.65E 1.07 4394.46 554643,73 5964649.09 8432.97 90.06 1.26 3571.13 4195.36N 4783.99E 1.57 4491.56 554645.43 5964746.24 8530.21 89,18 2.01 3571.78 4292,55N 4786,77E 1,19 4588,74 554647.55 5964843.45 8626.26 89.54 1,80 3572.85 4388.55N 4789.96E 0.43 4684.74 554650,11 5964939.45 8723.39 88.22 2.60 3574,75 4485.58N 4793.69E 1.59 4781,81 554653.19 5965036.50 8820.15 89.48 3.32 3576,69 4582.19N 4798.68E 1.50 4878.54 554657.55 5965133.13 8916,64 90.18 3.89 3576,98 4678.49N 4804.75E 0.94 4975.03 554662,97 5965229.45 9013.40 88.46 1.78 3578.13 4775.11N 4809.53E 2.81 5071.77 554667,12 5965326.10 9110.74 88.22 4,84 3580.95 4872,24N 4815.15E 3.15 5169.05 554672.09 5965423.25 9206.39 88,86 4.69 3583.38 4967,53N 4823.09E 0.69 5264,65 554679.40 5965518.58 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98,8ft above mean sea level) Vertical Section is from O.OON O,OOE on azimuth 3.65 degrees Bottom hole distance is 9319.28 Feet on azimuth 32.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated eonocó"Pmllips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo.23 PB1 Well path: GSS<0-532'>MWDw/Sag & Mag<561-12132'> Date Printed: 21-Jun-2004 .1. BAKlR HUGIIIS INTEQ Wellpath(Grid} Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing PositionCY} Position(X} Sectionrttl 9303.72 88.40 4,61 3585.71 5064.51N 4830,98E 0.48 5361.94 554686.64 5965615.60 9398,75 88,86 4.65 3587,98 5159.20N 4838.65E 0.49 5456.93 554693.68 5965710.33 9496.81 88.34 5.13 3590.38 5256,88N 4847,01E 0,72 5554,94 554701.39 5965808.05 9593.51 I 88,99 5.30 3592.63 5353,15N 4855.79E 0,69 5651.57 554709.53 5965904.37 9690.62 88.19 4,92 3595.02 5449,84N 4864.44E 0,91 5748.62 554717.54 5966001.11 9786.51 87.91 4.91 3598.28 5545.32N 4872.65E 0.29 5844.43 554725,11 5966096.63 9883.45 88.10 5.81 3601.66 5641.78N 4881.70E 0.95 5941.27 554733.52 5966193,14 9979,95 87.82 4.81 3605.09 5737.80N 4890.63E 1.08 6037.67 554741.81 5966289.21 10077.33 87,73 5.00 3608,87 5834.75N 4898.95E 0.22 6134.95 554749.48 5966386.20 10174.72 88.55 4.41 3612.03 5931.76N 4906.93E 1.04 6232.27 554756.82 5966483.25 10270.70 89.08 5.52 3614.02 6027.36N 4915.23E 1,28 6328.20 554764.49 5966578.90 10367,13 90.46 4.50 3614.41 6123.42N 4923,66E 1.78 6424.60 554772.27 5966675.00 10463.66 88,56 3.52 3615,23 6219.70N 4930.41 E 2.21 6521.12 554778.38 5966771.32 10560.28 88.00 4,15 3618.13 6316.06N 4936,86E 0,87 6617,70 554784.20 5966867.71 10658.08 87.82 4,77 3621.70 6413,50N 4944.47E 0,66 6715.42 554791.15 5966965.18 10753.68 85,67 3.89 3627,13 6508.67N 4951.67E 2.43 6810.85 554797.73 5967060.39 10851.36 88.40 1.55 3632,18 6606.09N 4956.30E 3.68 6908.37 554801,70 5967157,83 10948.38 88,19 1.82 3635,07 6703.03N 4959.15E 0.35 7005,29 554803.91 5967254.77 11045.18 88,28 1.57 3638,05 6799.74N 4962.01 E 0.27 7101.99 554806.13 5967351.49 11141.54 90.21 1.83 3639.32 6896.04N 4964.87E 2.02 7198.28 554808.35 5967447.80 11238.27 89.85 0.37 3639.27 6992.75N 4966.73E 1.55 7294.91 554809.56 5967544.51 11331.78 91.17 0.92 3638.43 7086.25N 4967.78E 1.53 7388.29 554810.00 5967638.00 11425.62 88.92 359.57 3638,36 7180.08N 4968.18E 2.80 7481.95 554809.77 5967731,83 11517.85 88.68 358.51 3640.29 7272,28N 4966.64E 1.18 7573.86 554807.62 5967824.00 11611.49 89.02 358.35 3642.17 7365.86N 4964.07E 0.40 7667.10 554804.43 5967917.56 11704.97 89.23 0.33 3643.60 7459,32N 4962.99E 2.13 7760.30 554802.73 5968011.00 11797.61 88.34 0.47 3645.56 7551,94N 4963.64E 0.97 7852,77 554802.77 5968103.61 11892.44 88,92 0.51 3647.83 7646.73N 4964.45E 0,61 7947.42 554802.95 5968198.40 11985.18 90.99 359.94 3647.90 7739.47N 4964.81E 2.32 8039.99 554802.70 5968291.13 12078.14 91.87 0.43 3645,58 7832.40N 4965.11E 1.08 8132.75 554802,38 5968384,05 12132.00 91.87 0.43 3643.83 7886.23N 4965.52E 0.00 8186.50 554802.43 5968437,87 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 9319,28 Feet on azimuth 32.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJ'Phillips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellbo.23 PB1 Wellpath: GSS<0-532'>MWDw/Sag & Mag<561-12132'> Date Printed: 21-Jun-2004 rli. ...,. INTEQ Comments MDrft] TVDrft] 7640.00 3495.83 8700,00 3574,09 9350.00 3586.91 10650,00 3621.39 12060,00 3646.15 12132.00 3643.83 Northrft] 3412.42N 4462.22N 5110.62N 6405.45N 7814.27N 7886,23N Eastfftl 4737.77E 4792.67E 4834.71E 4943.80E 4964.99E 4965.52E I Comment ;DTop Dip pt 1 Dip Pt2 Dip Pt3 Top B Proiected Data - NO SURVEY Hole Sections Diameter Start Start Start Start End End End Start Wellbore nn] MDfft] TVDrftl Northrft] Eastfft] MDrftl TVDfft] Northrftl Eastfftl 24.000 0.00 0,00 O.OON O,OOE 108.00 108.00 O.OON O.OOE 123 PB1 131/2 108.00 108.00 O.OON O,OOE 3705.00 2210.15 1017.06N 2176.76E 123 PB1 97/8 3705.00 2210.15 1017,06N 2176.76E 8047.00 3574.49 3809.96N 4768.46E 123 PB1 63/4 8047.00 3574.49 3809,96N 4768.46E 12132,00 3643.83 7886.23N 4965,52E 123 PB1 Casings Name Top Top Top Top S~Qe Shoe MDrftl TVOrftl Northfftl Eastfftl MDtftl TVDrftl 20" Conductor 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 123 PB1 10 3/4" Casino 0.00 0.00 O,OON O.OOE 3694.00 2206.33 1012.83N 2167.35E 123 PB1 7 5/8" Casino 0.00 0.00 O.OON O,OOE 8042.00 3573.99 3804.99N 4768.18E 123 PB1 4 1/2" Slotted Liner 7800.00 3534.99 3567.00N 4750,68E 13459.00 3705.20 9210.73N 5014.38E 123 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98,8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 9319.28 Feet on azimuth 32.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated I <:onocÓPhillips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska well.: 123 ~Ó '1- 07'1 Mi. Wellpath: MWD w/Mag&Sag<11986 - VdI.s 13460'> Date Printed: 21-Jun-2004 INTEQ Name 123 I Created . 30-May-2004 Name 123 I Govemment ID I I Last Revised 129-Jan-2004 1M Name Slot #123 SyStem Name AK-4 on NORTH AMERICAN DATUM 1927 FiêlB Name Kuparuk River Unit lEastinQ .. 487754.6208 NorthinQ 5948985,8206 I Coord System Name NÓÍ'thAliQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~·· True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O,OON O.OOE on azimuth 3,65 degrees Bottom hole distance is 10488.11 Feet on azimuth 28.56 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated n ()\)~ \ ," C~illips ConocoPhillips Alai, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska well.: 123 Wellpath: MWD w/Mag&Sag<11986 - 13460'> Date Printed: 21-Jun-2004 rei. Vel. INTEQ Wellpath ·(Grid) Report MO[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfft] 11892.44 88.92 0.51 3647.83 7646.73N 4964.45E 0.00 7947.42 554802,95 5968198.40 11986.35 86.46 0.52 3651.62 7740.56N 4965.30E 2.62 8041,11 554803.17 5968292.22 12079.74 87.73 1.63 3656,35 7833.81N 4967.05E 1.81 8134.28 554804.30 5968385.47 12172,95 87.26 1.23 3660.42 7926.90N 4969.37E 0.66 8227.33 554806,00 5968478.56 12266,04 87.94 1.00 3664,32 8019.89N 4971.18E 0.77 8320.25 554807.20 5968571.55 12356.13 89.20 1,93 3666.57 8109,92N 4973.48E 1,74 8410.24 554808.90 5968661.59 12453.03 90.64 1.22 3666.70 8206,78N 4976.14E 1,66 8507.08 554810,92 5968758.45 12546.24 90.15 1,20 3666.06 8299,97N 4978.11E 0.53 8600.20 554812.27 5968851.64 12640.41 89.63 0,83 3666.24 8394.12N 4979.78E 0.68 8694.27 554813,31 5968945.80 12733.20 88.59 2.73 3667.68 8486.85N 4982,66E 2.33 8786.99 554815.58 5969038.53 12822,68 87,67 3.24 3670,60 8576.16N 4987.32E 1.18 8876.42 554819.64 5969127.86 12912.53 87.26 2,33 3674.58 8665.81N 4991.68E 1,11 8966.17 554823,41 5969217.54 13003,58 86.01 2.13 3679,92 8756.64N 4995.22E 1.39 9057,03 554826.34 5969308.37 13093,89 84,09 1.33 3687.72 8846.56N 4997.94E 2.30 9146,95 554828.46 5969398.31 13184.65 85.89 3.08 3695.64 8936,90N 5001.42E 2.76 9237.33 554831.34 5969488.66 13275.53 87.93 3.44 3700.54 9027,50N 5006,57E 2.28 9328.07 554835,90 5969579.28 13364.64 88.49 2.14 3703,32 9116.46N 5010.91E 1.59 9417.12 554839.64 5969668,25 13401.90 88.80 2.10 3704,20 9153.68N 5012.29E 0.84 9454.36 554840.77 5969705.48 13460.00 89.20 2.10 3705.22 9211,73N 5014.42E 0,69 9512.43 554842,52 5969763.54 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O,OON O,OOE on azimuth 3.65 degrees Bottom hole distance is 10488.11 Feet on azimuth 28.56 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conc>cJ'Phillips ConocoPhillips Alél, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit, North Slope, Alaska well.: 123 Wellpath: MWD w/Mag&Sag<11986 - 13460'> Date Printed: 21-Jun-2004 mi. V_ INTEQ Comments MDlftl TVDlftl 7640.00 3495.83 8700,00 3574.09 9350.00 3586,91 10650.00 3621.39 12845.00 3671.53 13136.00 3691.75 13460,00 I 3705.22 Northrftl 3412.42N 4462,22N 5110.62N 6405.45N 8598.43N 8888.46N 9211,73N Eastfftl 4737,77E 4792.67E 4834,71E 4943.80E 4988.54E 4999.20E 5014.42E Comment DTop Dip pt 1 Dip Pt2 Dip Pt3 ¡Fault. 'I Top B Across Fault Projected Data - NO SURVEY Hole Sections Diameter Start Start Start Start End End End Start WeUbore [inl MDlftl TVDrftl Northrftl Eastfftl MDrftl TVDrftl Northrftl Eåstrftl 24,000 0.00 0.00 O.OON O,OOE 108.00 108.00 O.OON O.OOE 123 PB1 131/2 108.00 108,00 O.OON O.OOE 3705,00 2210.15 1017,06N 2176.76E 123 PB1 97/8 3705,00 2210.15 1017.06N 2176.76E 8047.00 3574.49 3809.96N 4768.46E 123 PB1 63/4 8047.00 3574.49 3809.96N 4768,46E 12132.00 3643.83 7886.00N 4968.43E 123 PB1 63/4 11950.00 3649.67 7704.26N 4964.97E 13460.00 3705.22 9211.73N 5014.42E 123 {ß'ãsinas Name Top Top Shoe Shoe Shoe Wellbore TVDrftl Northrftl TVDlftl Northrftl Eástfftl 20" Conductor 0.00 0.00 O.OON O.OOE 108,00 108.00 O,OON O.OOE 123 PB1 103/4" Casino 0.00 0.00 O.OON O.OOE 3694.00 2206,33 1012.83N 2167,35E 123 PB1 7 5/8" Casino 0.00 0.00 O.OON O,OOE 8042.00 3573.99 3804.99N 4768.18E 123 PB1 4 1/2" Slotted Liner 7800.00 3534,99 3567.00N 4750.68E 13459.00 3705.20 9210.73N 5014.38E 123 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98,8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10488.11 Feet on azimuth 28.56 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: New West Sak Producing Wells . . Subject: Re: New West Sak Producing Wells From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 06 Jul2004 06:25:50 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> ~O~-o~~ dO\.-\ - 0'\ ç Jerry, 0"'(. I looked at our 407 list and I don't show that we have received 90 on this well yet. I would suggest that the 407 reflect that the well was completed as a producer on gas lift. When the switch to ESP is made, then you can send the 404 as you plan. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: /""1 S: \ E.. - \ ð~ '- 1.. Tom: 1E-123 (PTD 2040740) is a new West Sak ESP producing well. The well has been completed but the surface facilities are not yet complete. Until all the electrical systems are in place the ESP pump cannot be operated. Operations wants to temporarily operate the well on gaslift production until the facilities are completed, which are not expected to be ready until the November time frame. There may be an additional 4 or 5 wells completed during the interim that will have the same issue. What kind of notification, if any, do you want to have to bring these wells on line with gaslift, and then report the change with the swap to ESP production? The situation does not fit in any particular category on the proposed matrix we were discussing the other day. As a suggestion, may I propose an email notification when the well is brought on line on gaslift, followed by a 10-404 when the swap is made to ESP? It will be a week or so before 1E-123 is ready so whatever we do right now can be used as a model for the remaining wells. Thanks for your feedback. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 7/6/20048:30 AM Re: Change in Procedure on lE-I23, lE-I23Ll, Permits # 204-074,... . . Subject: Re: Change in Procedure on 1E-123, 1E-123L1, Pennits # 204-074,204-075 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 10 Jun 200411:27:43 -0800 To: "McKeever, Steve" <Steve.McKeever@conocophillips.com> CC: "Ennis, J J" <J.J.Ennis@conocophillips.com> Steve, What you describe is how did the completions back when reasoning is to use a "better tool" and one whose crew ESPs. 3S is up and running so there should not be any proposal is acceptable. Please be sure that the rig contacts the Inspectors for the 3S BOP test. place a copy of this message in the well file. Please call with any questions. Tom Maunder, PE AOGCC I was in Kuparuk. Your has more experience running start up issues. Your I will McKeever, Steve wrote: Hi Tom- With regard to our conversation yesterday, listed below is the revised drilling procedure we are proposing for the completion of 1E-123 & 1E-123L1, the dual lateral well currently under construction. The approved Applications for Permit to Drill indicated that the final ESP completion would be run by Doyon #141. We would like to take advantage of the availability of a lower cost rig, Nabors 3s, to run that final completion. The configuration of that final completion will be as permitted¡ only the steps to get it into the ground have changed. At the current time, 10 am, June 10, the operation underway at the rig is Step # 4 below. The upper liner is in place and the drill pipe is being laid down. If this change in procedure is acceptable to the AOGCC without further documentation, can you please so indicate with a return e-mail to me? Thanks, Steve Revised Drilling Procedure for 1E-123 and 1E-123L1: 1. PU and run 4-1/2" slotted liner. 2. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 3. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 4. POOH, laying down drill pipe as required. 5. RIH with 4-1/2" open ended tubing with one gas lift mandrel (loaded with dummy valve) to window depth less 50 feet. Land tubing. Set BPV. 6. Freeze protect 10-3/4" x 7-5/8" annulus with diesel. 7. Nipple down BOPE, nipple up tree and test. Pull BPV. 8. Move Doyon Rig 141 off the well. Nabors 3s Rig Operations: 9. Move in and rig up Nabors Rig 3s. Nipple down tree, nipple up and test 13-5/8" x 5ksi RRA BOP stack. 10. Pull BPV. Circulate bottoms up. POOH with tubing, standing back. 11. Make up ESP drive section (motor only, no pump), other completion equipment as required and RIH to setting depth. Make up tubing hanger and land tubing. Set BPV. 12. Nipple down BOPE and nipple up and test tree. 13. Freeze protect tubing and tubing annulus with diesel. Post Rig Well Work Operations: 14. Rig up wire line unit. Pull BPV 15. Set gas lift valves in mandrels. Operate well on gas lift for ± 180 days. Iof2 6/10/2004 11 :27 AM Re: Change in Procedure on lE-I23, IE-I23Ll, Pennits # 204-074,... e . 16. Replace gas lift valves with blank dummy valves. 17. Run ESP through tubing. 18. Operate well with ESP. Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve.mckeever@conocophillps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 "One of the reasons people stop learning is that they become less and less willing to risk failure." - John W. Gardner 20f2 6/1 0/2004 11 :27 AM · ,e I I FRANK H. MURKOWSKI, GOVERNOR I / ~',ASIiA ORAND GAS CONSERVATION COMMISSION I Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field lE-123 ConocoPhillips (Alaska), Inc. Permit No: 204-074 Surface Location: 933' FSL, 630' FEL, Sec. 16, TllN, RI0E, UM Bottomhole Location: 403' FNL, 908' FEL, Sec. 10, TllN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill 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. 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 witness any required test. Contact the Commission's petroleum field inspector at (907) 65 -3 7 (pager). BY ORDER Q¡ THE COMMISSION DATED this~ day of May, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. Conoc~illipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 3, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1E-123 & 1E-123 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "B" and "D" sands. The main bore of the well will be designated 1E-123, and the lateral bore of the well will be designated 1E-123L1 Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-123 is May 15, 2004. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. Sincerely, '~.-~~l"\ï~ Randy Thomas Greater Kuparuk Area Drilling Team Leader 1a. Type of Work: Drill0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: _ STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 t57 w., RECEIVED MAY 04 2004 RedrillU 11 b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): ./ Surlace:933'FSL,630'FEL,Sec. 16, T11N,R10E,UM Top of Productive Horizon: 656' FNL, 1151' FEL, Sec. 15, T11N, R10E, UM Total Depth: 403' FNL, 908' FEL, Sec. 10, T11 N, R10E, UM / 4b. Location of Well (State Bas~¡P7Ia~¿:~,OrdinateS): 5''1~ f17. èA Surlace: x- ~5't' I ~'-f'Cy_ ~81 Zone- 4 16. Deviated wells: Kickoff depth: 300 18. Casing Program Size Hole 42" Casing 20"><34" 13.5" 9.875" 6.75" 10.75" 7.625" 4.5" 19 Total Depth MD (It): Casing Structu ral Conductor Surlace Intermediate Production Liner Perloration Depth MD (ft): 20. Attachments: Filing Fee Property Plat (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD perlOration Depth TVD (ft): Drilling Program0 Time v. Depth Plot U Seabed Report D Drilling Fluid Program 0 Date: ft. Maximum Hole Angle: 87.7° Specifications Weight Grade Coupling Length 94# K-55 Weld 80' 45.5# L-80 BTC 3832' 29.7# L-80 BTCM 7874' 12.6# L-80 Grant 5779' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size o D BOP SketchD Diverter Sketch D 21. Verbal Approval: Commission Representative: .1 ExploratoryU DevAl~tßlII?KJ(jas Cons. fã.oßtmi~~ÍI~¡fD Service D Development Gas CÀnchorage Single Zone 0 5. Bond: U Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-123 6. Proposed Depth: 12. Field/Pool(s): ,I 13345' MD TVD: 3742' Kuparuk River Field 7. Property Designation: '" West Sak Pool 13. Approximate Spud Date: 5/14/2004 ALK 25651 & 25648 8. Land Use Permit: ADL 469 & 466 9. Acres in Property: 2560 14. Distance to Nearest Property: 908' , @ TD 10. KB Elevation 15. Distance to Nearest Well within Pool: 16-101/104' @ 1329 (Height above GL): 28' RKB feet 17. Anticipated Pressure (see 20 AAC 25,035) Max. Downhole Pressure: 1834 psig I Max. Surlace Pressure: 1422 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2200' 770 sx AS Lite & 180 sx DeepCrete 3474' 160 sx DeepCrete 3742' slotted - no cement Top MD TVD 28' MD 108' 3860' 7902' 13345' 28' 28' 28 7566' 28' 28' 3510' Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve McKeever @ 265-6826 Printed Name R. Thomas Title Kuparuk Drilling Team Leader ~~ ~ Phone 2.':),I:ø>ö Date ';)"('$/0 '1 , \ Preaared bv Sharon AI/sua-Drake Commission Use Only Permit to Drill I API Number: I Permit APPror~" ? t i1see cover letter Number: de?> \--\ - 'C) ~ '-\ 50- D:? c; - d '"3> d CJ ~ - (J Ù Date: .) ,j I. ~/O for other requirements Conditions of approval: Samples required D Yes ~o Mud log requ' ed .bJ Yes ~ No H r gen sulfide measures D Yes%No Directional survey required~Yes tJ No \, \, \ \"'\.'0'1",\ ~C::)~ -\<ë"S \-. Signature COMMISSIONER BY ORDER OF THE COMMISSION 1~y Submit in duplicate Date: Form 10-401 Revised 3/2003 . ORfGINAL It .cation for Permit to Drill, We1l1E-123 Revision No.O Saved: 2-May-04 Permit It - West Sak Well #1E-123 Application for Permit to Drill Document MQximizE Well VQlu~ Table of Contents 1. Well Name............. .................................... ............ .... ..... ....... ....... ... .................. ...... ............ ........................... 2 Requirements of 20 AAC 25.005 (f)........ .................................................. ....... ................................. ......2 2. Location Summary................ ........... ............ ........... II·... ..... ....... ........... ............ ......... ............... ............... ... 2 Requirements of 20 AAC 25. 005( c)(2) ................... ........................... ............................ .........................2 Requirements of 20 AAC 25. 050(b).............. ....................... ........................................... ........................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7.. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Dri II i ng ·FI uid Program . ........... ... .............. .... ...... .... .... ..... ... .... ............... ........... ........ 5 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) ..................................................................................5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 6 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10. Seismic Analysis... ........................ ................. ...... ......... .................... .......... ........ .... ... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 ORIGINAL 1E-123 PERM/T /T.doc Page 1 0'8 Printed: 2-May-04 -- .ication for Permit to Drill, We1l1E-123 Revision No.O Saved: 2-May-04 12. Evidence of Bonding ........................................................................................\..... 7 Requirements of 20 AAC 25.005 (c)(12) 0 om ou UUU uu umumuu uuuuu uu uu uu mu uu uu uumuu.tJ~m uu 7 13. Proposed Drilling Program .................................................................11.-:"-... .........7 Requirements of 20 AAC 25.005 (c)(13) ......................................................................~.V... ....... ........7 '\ 14. g~:~i~e~~~t~ ~~~~:C ~~~~~~~~~~~.~~~~.~~.~~.~~.~.~.~~.~.I.~~.~~~.~.~;~~~~.. ... . ~...~~~.....~~~.~ 15. Attachments .......................................................................... ..... ....... .................8 ..... ........ ......... .... ......................... .... ....... .....~ .............. ........ 8 ................................. ... ........................................ 8 .7... ..... ..........................................8 .............. ............................... 8 1. Well Name ~ Requirements of 20 AAC 25.005 (f) .. Each well must be identified by a unique name designated by tli e. tor and a unique API number assigned by the commi..'iSion under 20 MC 25.040(b). For a well with multiple we!! branch~. , c. branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the Wi 'I. Ie operator and to the number assigned to the well by the commission. tAl'll ~ The well for which this Application is sUbmi~} be designated as 1E-123. 2. Location Summary , Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accom by each of the following items, except for an item already on file wIth the commission and ¡dentlfied in the application: (2) a plat Identifying the property and the wners and showing (A)the coordinates of the proposed location ell at the surface, at the top of each objective formation and at total depth referenced to governmental section lines. (B) the coordinates of the proposed !ocatiofo!j e we!! at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetf,çA rvey in the National Oceanic and Atmospheric Administration· (C) the proposed depth of the well at th't;l f eactl objective formation and at total depth· Location at Surface 1..(/ 933' FSL, 630' FEL, Section 16, TUN, R10E, UM ASP Zo~e 4 NAD 27 Coordinates . I RKB Elevation I 98.7' AMSL Northmgs: 5,959,781 Ei;~tm Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,964,243 E. 656' FNL, U51' FEL, Section 15, TUN, R10E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7,802 3,563 3,464 Location at Total D th ASP Zone 4 NAD 27 Coo/1 ates Northings: 5,969,7 Eastings: 554,810 403' FNL, 908' FEL, Section 10, TUN, R10E, UM Measured Depth, RKB: 13,345 Total Vertical Depth, RKB: 3,742 Total Vertical Depth, 55: 3,643 ~Jf1RJGINAL 1E-123 PERMIT IT. doc Page20fB Printed: 2-May-04 e e Application for Permit to Drill, We1l1E-123 Revision No.O Saved: 10-May-04 12. Evidence of Bonding.. ................... .................................................................. .........7 Requirements of 20 MC 25.005 (c)(12)................................................................................................. 7 13. Proposed Drilling Program ........................................................... .............. ......... ....7 Requirements of 20 MC 25.005 (c)(13)................................................................................................. 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14).................................................................................................8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan (14 pages) ..............................................................................................8 Attachment 2 Drilling Hazards Summary (1 page) .................................................................................8 Attachment 3 Cement Loads and CemCADE Summary (2 pagse).......................................................8 Attachment 4 Well Schematic (1 pages)................................................................................................8 REC~ MAY 1 2 2004 1. Well. Name Alaska Oil & Gas Cans. Commission ReqUIrements of 20 AAC 25.005 (f) ,dnrhn Each well must be identified by a unique name designated by the operator and a unique API numb@'~})@Jly the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-123. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 933' FSL, 630' FEL, Section 16, TUN, R10E, UM I RKB Elevation I 98.7' AMSL Pad Elevation 70.7' AMSL Location at Top of Productive Interval (West Sak "8" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,964,243 Eastings: 554,615 656' FNL, U51' FEL, Section 15, TUN, R10E, UM Measured Depth/ RKB: Total Vertical Depth/ RKB: Total Vertical Depth 55: 7,802 3,563 3,464 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,969,777 Eastings: 554,810 403' FNL, 908' FEL, Section 10, TUN, RlOE, UM Measured Depth/ RKB: 13,345 Total Vertical Depth/ RKB: 3,742 Total Vertical Depth 55: 3,643 1E-123 PERMIT IT. doc Page 2 of 8 Printed: 10-May-04 >-- Ar"ìlication for Pennit to Drill, Well 1 E-123 Revision No.O Saved: 2-May-04 '- and (O) other information required by 20 MC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Dnll (Form 10-401) must {l} include a plat, drawn to a suitable scale/ showing the path of t/7e proposed weJlbor~ including all adjacent wellboïes within 200 feet of any portion of the proposed wel¿' Please see Attachment 1: Directional Plan and (2) for all wells wit/7in 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of tf]e application by certified mail; or (B) state that the applicant is the only affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Onll must be accompanied by each of the fa/lowing item~ except for an item already on file with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25. 03~ 20 AAC 25.036; or 20 MC 25.03~ as applícable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-123. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (4) information on dnlling hazard~ including (A) the maximum downhole pressure that may be encounterec£ criteria used to determine it, and maximum potential surface pressure based on a methane gradient,' The expected reservoir pressures in the West Sak sands in the lE-123 area vary from 0.42 to 0.49 psi/ft, / or 8.1 to 9.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1,422 psi, calculated thusly: MPSP =(3,742 ft)(0.49 - 0.11 psi/ft) = 1,422 psi / (B) data on potential gas zone~' The well bore is not expected to penetrate any gas zones. j and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata/ lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests" as required under 20 MC 25.030(l); ORIGIN A:. 1E-123 PERMIT IT. doc Page 3 of 8 Printed: 2-May-04 ^ "lication for Permit to Drill, Well 1 E-123 Revision No.O Saved: 2-May-04 1E-123 will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accornpanied by each of the fo//owing item~ except for an item a/reaäyon file wIth the commission and Identified in the app/iœtion: (6) a complete proposed casl/7g and cementing program as required by 20 MC 25. 030" and a description ot' any slotted liner; pre- perforated /iner; or screen to be insta/led/ Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 42 6-3/4" Lower Lateral (lE-123) 6-3/4" Upper Lateral (lE-123 Ll) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dnïl must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (7) a diagram and description of the diverter systelì7 as required by 20 MC 25. 03~ unless this requirement is waived by tfle commission under 20 MC 25.03S(h)(2J· CsglTbg 00 (in) 20 X 34 10-3/4 7-5/8 4-1/2 slotted 4-1/2 slotted 13-1/2 9-7/8 Weight (Ib/ft) 94 Length (ft) 80 Top Mo/TVo (ft) 28 / 28 Cement Program Cemented to su rface with 260 d ArcticCRETE Cemented to Surface with 770 sx ASLite Lead, 180 sx DeepCRETE Tail Cement Top planned @ 7000' MD / 3348' TVD. Cemented w/ 160 sx DeepCRETE Slotted- no cement Slotted- no cement A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-123. Please see diagrams of the Doyon 141 diverter system on file with the Commission. Btm Mo/TVD (ft) 108 / 108 Grade Connection K55 Welded 45.5 L-80 3832 28 / 28 3860 /2200 BTC 29.7 L-80 28 / 28 7902 / 3474 BTCM 7874 12.6 7566/ 3510 13,345 / 3742 L-80 Grant Prideco DWC/C 5779 12.6 7526/ 3500 13340 / 3679 L-80 Grant Prideco DWC/C 5814 oR'tHINlYXL . 1E-123 PERMIT IT. doc Page 4 of 8 Printed: 2-May-04 - Aonlication for Permit to Drill, Well 1 E-123 Revision No.O --' Saved: 2-May-04 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Dnll must be accompanied by each of the foflowing ítem~ except for an item already on file t"v'ith t1e commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as æquired by 20 MC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.5 ~9.4 Funnel Viscosity 150-200 150-200 (seconds) Yield Point 30-60 30-60 (cP) Plastic Viscostiy 8-15 11- 22 (lb1100 sf) 10 second Gel 10-30 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 Strength (lb1100 sf) pH 8-9.5 8-9.5 API Filtrate 8-15 <8 (cc 130 min)) Solids (% Vol) 5-8 5-8 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (extended bentonite) lO-3/4r/Casing Shoe to 7-5/8" Casing Point Initial Value Final Value ~9.2* 8.8 to 9.0 45-60 45-55 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH API Filtrate (cc 130 min)) Solids (% Vol) 18-28 18- 30 9-16 10-18 10-25 10-25 15-25 15-25 8-9.5 8-9.5 <6 <5.5 5-8 6-11 *9.6 ppg if hydrates are encountered ORIGINAL Base of Permafrost to lO-3/4r/ Casing Point Initial Value Final Value ~9.4* <9.4* 150 65-75 20-40 18- 30 12-30 12-24 10-25 10-25 20-40 20-40 8-9.5 8-9.5 <8 <6 5-8 6-10 1E-123 PERMIT IT. doc Page 5 of 8 Printed: 2-May-04 ~ ·lication for Permit to Drill, Well 1 E-123 Revision No.O Saved: 2-May-04 Lateral Mud Program (MI FloPro NT) BID sand laterals Initial Value Final Value Density (ppg) 9.0 9.7 J Funnel 45-60 45-60 Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Tau 0 Chlorides (mgll) pH API filtrate (cc 130 min) **HTHP filtrate (cc 130 min) MBT (lb I gal) ***Solids (% Vol) 22-30 22-30 8-12 8-12 4-7 4-7 65-80K 65-80K 8-9.5 8-9.5 <6 <6 <10 <10 <5 <5 <6-9 <6-9 U HTHP to be run at 800 F ...... The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit, to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratOlY or stratigraphic test well a tabulatJon setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 2S033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (10) for an explorator¡ or stratigrapl7ic test well, a seismic refraction or reflection analysis as required by 20 MC 25-061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applicatIon for a Permit to Drill must be accompanied by each of the follol/ling items; except for an item already on file wIth the commissIon and identified 1/7 the applIcation: (11) for a well dr/lied from an offshore platfOlm¡ mobile bottom-founded structure¡ jack-up rig or floating dn//íng vessel an analysis of seabed condittons as required by 20 MC 25.061(b)/ Not applicable: Application is not for an offshore well. O'RVG/iNPit· 1E-123 PERMIT IT. doc Page 6 of 8 Printed: 2-May-04 A["Il"\lication for Penn it to Drill, Well 1 E-123 Revision No.O -' Saved: 2-May-04 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the foílowing items; except for an item already on file with the commission and Identified in the app/ícation: (12) evidence showing tllat the requirements of 20 AAC 25.025 {Bondíng}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the app/ícation: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 3860' MD / 2200' ïVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. ./ t..l¡I<'~ RES 38«/ ~ T.D~ í~ .5!-¿b<- /~'h.¿I/¿r 6. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of ß . float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. S-' /D ~ óf 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 7,902 MD / 3,574' ïVD. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 7,000 MD / 3348 ïVD if Ugnu formation is not oil bearing. Top of cement to be 5,000 MD / 2822 ïVD if Ugnu is oilbearing.)) and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. ./' 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud: Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). ,/ 14. Directionally drill 6-3/4" hole to TD at +/- 13,345' MD / 3,742' ïVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. PU and run 4-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 7,566' MD / 3,510'. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. Note: Remaining operations are covered under the lE-123Ll Application for Permit to Drill, and are provided here for information only. ORIGINAL 1E-123 PERMIT IT. doc Page 7 of 8 Printed: 2-May-04 A ìlication for Permit to Drill, Well 1 E-123 Revision No.O Saved: 2-May-04 18. Run and set Baker WindowMaster whipstock system¡ at window point of 7¡526' MD / 3¡500' ìVD, the top of the 0 sand. 19. Displace hole to used mud from lower lateral at 9.7 ppg. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 21. Displace to new drilling mud at 9.7 ppg. Drill to TO of 0 sand lateral at 13,340' MD / 3¡679' ìVD¡ as per directional plan. 22. POOH¡ back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. Displace liner annulus and liner to 9.7 ppg weighted brine. POOH. 27. POOH¡ laying down drill pipe as required. 28. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 29. Nipple down BOPE¡ nipple up tree and test. Pull BPV. 30. Set BPV and move rig off. 31. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus¡ taking returns from tubing and allowing to equalize. 32. Rig up wire line unit. Pull BPV 33. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 34. Replace gas lift valves with blanl dummy valves. 35. Run ESP through tubing. 36. Operate well with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following item~ except for a/1 item already on file wIth the commission and Identified in the application: (14) a general descr~Dtiof) of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids .J into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE pad¡ hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well¡ or stored¡ tested for hazardous substances¡ and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan (14 pages) Attachment 2 Drillíng Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematic (1 pages) QR~G1NAL ~~ t-:' 1E-123 PERMIT IT. doc Page 8 of 8 Printed: 2-May-04 Conocri'Phillips ConocoPhillips AlaSKa, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slopè, Alaska PROPOSAL1:fSTING Page 1 Wellbore: 1 E-123 Well path: 1E-123 Ver#3 Date Printed: 28-Apr-2004 r&ií. BAKER HUGHES INTEQ WeJIÞ9r~____ _ _ _________ ~-ªme ___ _ ~ _____ ________ ____ ..1E-123 _____~ ¡ Created .29-Jan-2004 i Last Revised ¡ 27 -Apr-2004 -~--- ---~ ------- Name 123 . Government ID Well -----~-.- -. ------------ -- ------ - ---I GridNorthinQ ; 5960520.0000 ,Grid Eastinq ¡ 549890.0000 ¡ Latitude I N70 18 10.4942 Slot Name Slot #123 Installation -~=;i~-~~_--_~~_~ -_~-=~ - - ~~astin~50528.1946 I Northinq , 5959591.1090 I Coord System Name I North Aliqnment AK-4 on NORTH AMERICAN DATUM 1927 daturl -' True ----~- -- ----- --------- Field ------ ----- -- -. --- --------- ---- I Eastinq 487754.6208 ¡ Northinq 5948985.8206 I Coord System Name J North Aliqnment AK-4 on_ NORTH AMERICAN DATUM 1927 daturl True Name Kuparuk River Unit i Created By ------~- ------ r---------- ¡Comments ------ ---------- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ~- ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 1 E-123 Wellpath: 1 E-123 Ver#3 Date Printed: 28-Apr-2004 r,¡. BAKER HUGHES INTEQ !Wellpath Report__ I Station I MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Station Dogie Vertical Station Comment Position(Grid Position(Grid g Section[f North) East) [deg/1 t] OOft] I 0.00 0.00 0.00 0.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 Tie on f- I 100.00 0.00 0.00 100.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 I 200.00 0.00 0.00 200.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 - I 300.00 0.00 ----º.OO 300.00 O.OON O.OOE 5960520.00 549890.00 0.00 0.00 KOP, End of Hold 400.00 3.00 65.00 399.95 1.11 N 2.37E 5960521.12 549892.36 3.00 1.26 ¡ 500.00 6.00 65.00 499.63 4.42N 9.48E 5960524.48 549899.45 3.00 5.02 600.00 9.00 65.00 598.77 9.94N 21.31 E 5960530.08 549911.24 3.00 11.27 633.33 10.00 65.00 631.64 12.26N 26.30E 5960532.44 549916.21 3.00 13.91 Bid 5/100, End of BuildfTurn 1 733.33 15.00 65.00 729.24 21.41N 45.91 E 5960541.71 549935.76 5.00 24.29 -I 833.33 20.00 65.00 824.58 34.11 N 73.15E 5960554.59 549962.92 5.00 38.70 Bid 6/100, End of Build 933.33 26.00 65.00 916.59 .30.62N 108.55E 5960571.33 549998.20 6.00 57.43 ,_ 1033.3~_~ 32.00 65.00 1004.01 71.10N 152.47E 5960592.10 550041.98 6.00 80.66 , i 1133.33 38.00 65.00 1085.89 95.33N 204.43E 5960616.67 550093.77 6.00 108.15 I ¡ 1233.33 44.00 65.00 1161.33 123.04N 263.86E 5960644.78 550153.01 6.00 139.60 i 1333.33 50.00 65.00 _1229.50 153.93N 330.11E 5960676.11 550219.05 6.00 174.65 i 1433.33 56.00 _65.00 12-ª-9.65 187.67N 402.46E 5960710.32 550291.16 6.00 21~_ 1533.33 62.00 65.00 1341 .13 223.88N 480.11E 5960747.04 550368.56 6.00 254.00 1633.33 68.00 65.00 1383.37 262.16N 562.21 E 5960785.86 550450.40 6.00 297.44 1641.50 6ML 65.00 1386.40 265.37N 569.09E 5960789.11 550457.25 6.00 301.08 EOC, End of Build 1700.00 68.49 65.00 1407.85 288.37N 618.41E 5960812.44 550506.42 0.00 327.17 ¡ 1800.00 68.49 65.00 1444.52 327.69N 702.73E 5960852.31 550590.4 7 0.00 371.78 1900.00 68.49 65.00 1481.18 367.01 N 787.05E 5960892.19 i 550674.52 0.00 416.39 2000.00 68.49 65.00 1517.85 406.32N 871.37E 5960932.06 550758.56 0.00 461.00 2035.87 68.49 65.00 1531.00 420.43N 901.61 E 5960946.36 550788.71 0.00 477.00 Base Permafrost 2100.00 68.49 65.00 1554.52 445.64N 955.69E 5960971.94 550842.61 0.00 505.61 2200.00 68.49 65.00 1591.1ß 484.96N 1040.01 E 5961011.81 550926.66 0.00 550.22 2300.00 68.49 65.00 1627.85 524.28N 1124.32E 5961051.68 551010.71 0.00 594.83 2400.00 68.49 65.00 1664.52 563.60N 1208.64E 5961091.56 551094.75 0.00 639.44 2500.00 68.49 65.00 1701.18 602.92N 1292.96E 5961131.43 551178.80 0.00 684.05 2600.00 68.49 65.00 1737.85 642.24N 1377 .28E 5961171.30 551262.85 0.00 728.66 ..---2633.14 68.49 65.00 1750.00 655.27N 1405.22E 5961184.52 551290.70 0.00 743.44 Top T-3 2700.00 68.49 65.00 1774.51 681.55N 1461 .60E 5961211.18 551346.90 0.00 773.27 ~ i 2800.00 68.49 65.00 1811.18 720.87N 1545.92E 5961251.05 551430.94 0.00 817.88 2900.00 68.49 65.00 1847.85 760.19N 1630.23E 5961290.92 551514.99 0.00 862.49 3000.00 68.49 65.00 1884.51 799.51 N 1714.55E 5961330.80 551599.04 0.00 907.10 3100.00 68.49 65.00 1921.18 838.83N 1798.87E 5961370.67 551683.08 0.00 951.71 3200.00 68.49 65.00 1957.85 878.15N 1883.19E 5961410.54 551767.13 0.00 996.32 3300.00 68.49 65.00 1994.51 917.47N 1967.51E 5961450.42 551851.18 0.00 1040.92 i 3400.00 68.49 65.00 2031.18 956.78N 2051.83E 5961490.29 551935.23 0.00 1085.53 r- I 3462.24 68.49 65.00 2054.00 981.26N 2104.31E 5961515.11 551987.54 0.00 1113.30 Top K-15 3500.00 68.49 65.00 2067.84 996.10N 2136.15E 5961530.16 552019.27 0.00 1130.14 3600.00 68.49 65.00 2104.51 1035.42N 2220.4 7E 5961570.04 552103.32 0.00 1174.75 3700.00 68.49 65.00 2141.18 1074.74N 2304.78E 5961609.91 552187.37 0.00 1219.36 J ~ 3800.00 68.49 65.00 2177.84 1114.06N 2389.10E 5961649.79 552271 .42 0.00 1263.97 ~ 3860.43 68.49 65.00 2200.00 1137.82N 2440.06E 5961673.88 552322.21 0.00 1290.93 103/4 CSG 3900.00 68.49 65.00 2214.5L 1153.38N 2473.42E 5961689.66 552355.46 0.00 1308.58 4000.00 68.49 65.00 2251.18 1192.69N 2557.74E 5961729.53 552439.51 0.00 1353.19 4100.00 68.49 65.00 2287.84 1232.01N 2642.06E 5961769.41 552523.56 0.00 1397.80 4200.00 68.49 65.00 2324.51 1271.33N 2726.38E 5961809.28 552607.61 0.00 1442.41 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated " ."Y ORtGtNA1- ......-- ConocoPhillips ConocoPhillips Alaška, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slopè~ Alaska Well~ªth R~~ort_~_~ MD[ft] , Inc[deg] 'Azi[deg] ¡ TVD[ft] _4300-,Q{L: 68.49 .1i5~.Qº-~~~361.18 --- --- ------) _ 4400.QO_ ~_._6~8-,~9. _, ~5.00 2397.84 4500.00 68.49 I 65.00 2434.51 4600.00 :-.~_~8-,-'l9____~0_0 2471.18 4700.00 68.49 65.00 2507.84 4800.00 68.49 65.00 2544.51 4900.00 68.49 65.00 I 2581.17 5000.00 68.49 65.00 2617.84 5036.02_u~ _6Jt49.__-º-5.00 2631.05 5100.00· 68.34 62.94 2654.59 _~5200.Qº-:~~_QJLHL_. _. þ9.72__~.___2§91.65 _~Q.Q.ºº _~ ~ _6fLO.A~ . ~ ~ QEL"HL_ 2728.97 ~_ 54QQJ).o__~.._6} J1.8_ _ .5_:t~_~66.42 u15ÞOO.OO~,~ ßl~.9JL.. .50-,-0_2 2803.92 ~.Q4ª,-~6.... _ _68.0J.__.48~46_L~822.00 ~º-O-'-º,O... ._6.8..0ß_l. .A.6...Zß_L 2841.36 ..2..QO___ºCL;.. ~ _6.8.1.9._ A.3-,~: 2878.63 5800.00 68.38 40.33 2915.63 5844.~_-ºª,~9._ _~~90 2931.99 5900.00! 68.49 38.90 2952.34 6000.00. 68.49 38.90 2989.00 6100.00' 68.49 38.90 3025.67 6200.00 68.49 38.90! 3062.33 -.9297.28_.-º6.49_:._ ~8.90 3098.00 6300.00. 68.49 ; 36.90 I 3099.00 6375.48 ~n ~66A9.~..J_ 36.9º--! 3126.67 __6400.0~. _1i8A~~..;_ 38~3135.66 6480.02: 68.49 . 38.90 ' 3165.00 -º.500.00... ~6i4.9...C 38.902_ 3172.33 6575.48· 68.49 . 38.90 i 3200.00 ._-~-~ . -----+ - I _6600.0-º-; _6ß-,Q.L; _ 37.85 I 3208.97 6700.00: 69.01 33.58 3245.16 ~OO.QO-L. _Q9...5A-_i. 2.9.34_..L_3260.57 6900.00; 70.17 i 25.14 i 3315.02 6986.73 70.80 21.52 3344.00 ; 7000.00 I 70.90 20.97 3348.35 7100.00' 71.73 ; 16.84 3380.40 7200.00__.-n....64 ___.-1.ZH..J 3411.00 7300.00 73.64: 8.70 ! 3440.02 7400.illLL.J4.71 _: 4.69 ! 3467.30 7426.09_,-._TIi-,ºº-~_.-3,~ I 3474.12 7500.lliL...J5.00 _L...3·65 i 3493.25 7526.09. 75.00 3.65: 3500.00 ----.----- ---- - - - :-- --~- ~-- 760QJliLJ5.JllL.l_ 3.65 i 3519.13 7644.58. 75.00 3.65 I 3530.67 7674~04:··7¡3:18~:--·· 3.65 I 3538.00 _ 7744.58.:_.u.Z~0-º. ---,-._~.~_U553.16 North[ft] East[ft] Station Position(Grid North) 1310.65N 2810.70E 5961849.15 1349.97N 2895.01E 5961889.03 1389.29N 2979.33E 5961928.90 1428.61N 3063.65E 5961968.77 1467.92N 3147.97E 5962008.65 1507.24N 3232.29E 5962048.52 1546.56N 3316.61 E 5962088.39 1585.88N 3400.93E 5962128.27 1600.04N 3431.30E 5962142.63 1626.15N 3484.76E 5962169.09 1670.70N 3566.23E 5962214.17 1719.71 N 3644.99E 5962263.71 1773.06N 3720.81E 5962317.55 1830.59N 3793.49E 5962375.56 1859.81 N 3827.38E 5962404.99 1892.15N 3862.82E 5962437.57 1957.57N 3928.62E 5962503.41 2026.66N 3990.70E 5962572.91 2058.53N I 4017.08E 5962604.96 2098.73N 4049.51 E 5962645.36 2171.13N 4107.94E 5962718.14 2243.54N 4166.36E 5962790.93 2315.94N 4224.78E 5962863.71 2386.38N 4281.61E 5962934.52 2388.34N 4283.20E 5962936.49 2443.00N 4327.30E 5962991.43 2460.75N 4341.63E 5963009.28 2518.69N 4388.38E 5963067.52 2533.16N 4400.05E 5963082.06 2587.81N 4444.15E 5963137.00 2605.70N 4458.31E 5963154.98 2681.37N 4512.72E 5963231.01 2761.12N 4561.52E 5963311.08 2844.57N 4604.4 7E 5963394.80 2919.62N 4636.83E 5963470.05 2931.31N 4641.38E 5963481.77 3020.91 N 4672.05E 5963571.57 3112.94N 4696.33E 5963663.74 3206.95N 4714.12E 5963757.86 3302.48N ¡ 4725.32E 5963853.45 3327.60N ¡ 4727.16E 5963878.58 3398.84N; 4731.70E 5963949.85 3423.99N ¡ 4733.31 E 5963975.00 3495.24N 4737.86E 5964046.27 3536.21N 4740.60E 5964089.26 3566.69N 4742.42E 5964117.74 3635.43N 4746.80E 5964186.51 PROPOSALL'íSTING Page 3 Wellbore: 1E-123 Wellpath: 1E-123 Ver#3 Date Printed: 28-Apr-2004 "1. BAKER HUGHES INTEQ Statioll I Dogie ¡Vertical i Station Comment Position(Grid i g : Section[f¡ East) [deg/1 . t] ! OOftl 0.00 ! 1487.02; 0.00 ; 1531.631 0.00 i 1576.241 0.00 ! 1620.85: 0.00 1665.46: 0.00 1710:071 0.00: 1754.681 0.00 ¡ 1799.281 0.00 1815.35! Tm 3/100. 3DXS Kick off Point 3.00 1844.811 3.00 1894.46i 3.00 1948.39: 3.00 2006.46 i 3.00 2068.51! 3.00 2099.82!Top UQnu C 3.00 2134.351 3.00 2203.83: 3.00 2276.74i 3.00 2310.23 i EOC. End of BuiJdfTum 0.00 2352.401 0.00 2428.38i 0.00 2504.361 0.00 2580.341 0.00 2654.25!Top UQnu B 0.00 2656.321 0.00 2713.671 Start 200' Pump TanQent 0.00 2732.301 . 0.00 2793.091 Top UQnu A 0.00 2808.281 i 0.00 2865.631 End 200' Pump Tangent, BldfTm 4/100, End ¡Hold 4.00 2884.36 i 4.00 2963.37! 4.00 3046.07; 4.00 3132.081 4.00 3209.04iK-13 4.00 3221.001 4.00 3312.371 4.00 3405.76: 4.00 3500.71 ¡ 4.00 3596.761 4.00 3621.941 EOC. End of BuildfTum 0.00 3693.331 0.00 3718.53Top West Sak DJ WS 1E X5 D TOP ! RVS0092503. End of Hold 0.00 3789.921 0.00 3832.991 Bid 4/100. 2DJ Kick off Point 4.00 j 3861.521 C 4.00 ¡ 3930.401 552691.65 552775.70 552859.75 552943.80 553027.84 553111.89 553195.94 553279.99 553310.26 553363.53 553444.71 553523.13 553598.59 553670.88 553704.56 553739.79 553805.14 553866.76 553892.93 553925.09 553983.02 554040.96 554098.89 554155.25 554156.83 554200.56 554214.76 554261.12 554272.70 554316.43 554330.47 554384.37 554432.63 554475.03 554506.88 554511.35 554541 .42 554565.10 554582.26 554592.82 554594.49 554598.56 554600.00 554604.07 554606.53 554608.16 554612.09 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from D.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINA"- .W"" ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 1 E-123 Well path: 1 E-123 Ver#3 Date Printed: 28-Apr-2004 r'¡. BAKER HUGHES INTEQ WellpattLReport ------- MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Station Station Dogie Vertical Station Comment Position(Grid Position(Grid g Section[f North) East) [deg/1 t] OOft] 7802.15 -ªL~î__ 3.65 3563.00 3692.03N 4750.42E 5964243.12 554615.33 4.00 3987.12 Top West Sak B _ 7844.58 83.00 3.65 3568.79 373~.98N 4753.09E 5964285.09 554617.72 4.00 4029.15 7902.15 85.31 3.65 3574.65 3791.13N 4756.74E 5964342.26 554620.99 4.00 4086.42 7 5/8 CSG, 7 5/8in Casinq I 7990.87 ª8.86 3.65 __ 3579.16 3879.54N 4762.38E 5964430.69 554626.05 4.00 4175.01 EOC, End of Build - I 8000.00 88.86 3.65 3579.34 3888.65N 4762.97E 5964439.81 554626.57 0.00 4184.14 8100.00 88.86 3.65 3581.33 3988.43N 4769.33E 5964539.61 554632.27 0.00 4284.12 8200.00 88,86 3.65 3583.32 4088.21 N 4775.70E 5964639.42 554637,98 0.00 4384.10 8300.00 88.86 3.65 3585.31 4187.98N 4782.07E 5964739.23 554643.68 0.00 4484.08 8400.00 88.86 3.65 :l587.30 4287.76N 4788.44E 5964839.04 554649,39 0.00 4584.06 ----~---- 8500.00 88,86 3.65 3589.29 4387.54N 4794.81 E 5964938.84 554655.09 0.00 4684.04 8600.00 88.86 3.65 3_591.28 4487.32N 4801,17E 5965038.65 554660.80 0.00 4784.02 -~~----- 8700.00 88,86 3.65 3593.27 4587.09N 4807.54E 5965138.46 554666.50 0,-00 4884.00 8800.00 _~8-,-8Q_ 3.65 3595.26 4686.87N 4813.91 E 5965238.26 554672.21 0.00_ 4983.98 ~OO.OO 88,86 _~.65 3597.25 4786.65N 4820.28E 5965338.07 _---º-º-16ll.91 0.00 5083.96 -----~--- 9000.00 __88,8Q__. 3.65__,_359~L24 4886.42N 4826.65E 5965437.88 554683.62 0.00 5183.94 -"-------- 9100.00 88,86 3,65 3601.23_3986.20N 4833.01 E 5965537.69 I 554689.32 0.00 5283.92 9200.00 88.86 3.65 3603.22 5085.98N 4839.38E 5965637.49 i 554695.0:L_0.00 5383.90 9300.00 88,86 3.65 3605.21 5185.76N 4845.75E 5965737.30 554700.73 0.00 5483.88 9339.77 88.86 3.65 3606.00 5225.44N 4848.28E 5965777.00 554703.00 0.00 5523.65 Drop 3/100, WS 1 E X5 B-MDPT#1 RVSD021804, 3DJ Kick off Point 9366.03 88.07 3.65 3606.70 5251.63N 4849.95E 5965803.20 554704.50 3.00 5549.89 EOC, End of Droprrurn 9400.00 88.07 3.65 3607.84 5285.52N 4852.11E 5965837.09 554706.43 0.00 5583.85 9500.00 88.07 3.65 3611.21 5385.26N 4858.47E 5965936.86 554712.13 0.00 5683.79 9600.00 88.07 3.65 3614.57 5485.00N 4864.83E 5966036.63 554717.83 0.00 5783.73 9700.00 88.07 3.65 3617.94 5584.74N 4871.19E 5966136.41 554723.52 0.00 5883.68 9800.00 88.07 3.65 3621,30 5684.48N 4877.55E 5966236,18 554729.22 0.00 5983.62 9900.00 88.07 3.65 3624.66 5784.22N_4883.91 E 5966335.95 554734.91 0.00 6083.56 10000.00 88.07 3.65 3628.03 5883.96N 4890.27E 5966435.72 554740.61 0.00 6183.51 10100.00 88.07 3.65 3631.39 5983.70N 4896,63E 5966535.49 554746.31 0.00 6283.45 10200.00 88.07 3.65 3634.76 6083.44N 4902.99E 5966635.26 554752.00 0.00 6383.39 10300.00 88.07 3.65 3638.12 6183.18N 4909.35E 5966735.03 554757.70 0.00 6483.34 10400.00 88,07 3.65 3641 .48 6282.93N 4915.71E 5966834.80 554763.40 0.00 6583.28 10500.00 88.07 3.65 3644.85 6382.67N 4922.07E 5966934.57 554769.09 0.00 6683.22 10600.00 88.07 3,65 3648.21 6482.41 N 4928.43E 5967034.34 554774.79 0.00 6783.17 10700.00 88.07 3.65 3651.57 6582.15N 4934.79E 5967134.12 554780.49 0.00 6883.11 10800,00 88.07 3.65 3654.94 6681.89N 4941.15E 5967233.89 554786.18 0.00 6983.05 10900.00 88.07 3.65 3658.30 6781.63N 4947.51E 5967333.66 554791.88 0.00 7083.00 11000.00 88.07 3.65 3661.67 6881.37N 4953.87E 5967433.43 554797.58 0.00 7182.94 11100.00 88.07 3.65 3665,03 6981.11 N 4960.23E 5967533.20 554803.27 0.00 7282.88 11200.00 88.07 3.65 3668.39 7080.85N 4966.59E 5967632.97 554808.97 0.00 7382.83 11218.07 88.07 3.65 3669.00 7098.88N 4967.74E 5967651.00 554810.00 0.00 7400.89 Bldrrrn 3/100, WS 1E X5 B-MDPT#2 RVSD021804, 3DJ Kick off Point 11300.00 88.54 1.23 3671.42 7180.69N 4971.22E 5967732.83 554812.94 3.00 7482.76 ~1333.25 88.73 0.25 3672.21 7213.93N 4971.66E 5967766.06 554813.16 3.00 7515.95. EOC, End of Buildrrurn 11400.00 88.73 0.25 3673.69 7280.66N 4971.95E 5967832.79 554813.01 0.00 7582.57 11500.00 88.73 0.25 3675.91 7380.63N 4972.40E 5967932.75 554812.79 0.00 7682.37 11600.00 88.73 ,.-1>.25 3678.12 7480.61 N 4972.84E 5968032.72 554812.57 0.00 7782.17 11700.00 88.73 0.25 3680.34 7580.58N 4973.29E 5968132.68 554812.35 0.00 7881.97 ~OO.OO 88.73 0.25 3682.56 7680.56N 4973.73E 5968232.65 554812.13 0.00 7981.77 All data is in Feet unless otherwise stated Coordinates are from Slot MOos are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ÜR IGI N'A' .. '- Conocri"Phillips ConocoPhillips Aléì§1(a, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska .Well~ªJh R@I!-ort MD[ft] ·Inc[deg] : Azi[deg] . TVD[ft] -Í1900,QQ~. _ 88.L3__:__-º,ZP__ 12000.00 88.73 0.25; 121 OO.OO··n 8&73---¡---025 _1220Q,.Q_Q~__--ª-ª.1~_~~ 12300.00 88.73 0.25 12316.53 88.73 0.25 3684.77 3686.99 3689.20 3691.42 3693.63 3694.00 12393.85 86.42 0.40 3697.27 12400.º-º- _ß_9__A2 _L_. 0.40 ----'-- 3697.66 12500.00' 86.42 0.40 3703.91 12600.0Q, .-ß.Q.42.._ _.___1>.40 3710.16 ....:!2QZ~-'-º-4..._8_6.42_~_OAO ¡ 3714.77 -1?700,0!L __ JE.2_0__ _!_ _.Q...3_3__ j~71§.23 12717.30' 87.72 . 0.29 ' 3717.00 ____ -0- ____________ 12800.00 87.72 0.29 3720.29 12-900~OO-:-__i7~7i~J~._::i29__=_ 3724.27 '13000.00; 87.72 0.29 3728.24 13100.00 _!37,IZ__L_0,Z9--1__ 3732.22 13200.00 87.72 0.29 3736.20 13300.00 87.72 0.29 3740.18 ,/ 13345.86: 87.72 0.29 3742.00 North[ft] 7780.53N 7880.51 N 7980.48N 8080.45N 8180.43N 8196.95N 8274.19N 8280.34N 8380.12N 8479.90N 8553.39N 8579.70N 8596.99N 8679.62N 8779.54N 8879.46N 8979.38N 9079.30N 9179.22N 9225.04N East[ft] 4974.18E 4974.62E 4975.07E 4975.51 E 4975.95E 4976.03E 4976.47E 4976.51 E 4977.21E 4977 .91 E 4978.42E 4978.59E 4978.69E 4979.1 DE 4979.61E 4980.11 E 4980.61 E 4981.12E 4981.62E 4981.85E PROPOSAL'-rfSTING Page 5 Well bore: 1E-123 Well path: 1 E-123 Ver#3 Date Printed: 28-Apr-2004 r&ií. BAKER HUGHES INTEQ Station Station Position(Grid Position(Grid North) East) 5968332.62 5968432.58 5968532.55 5968632.51 5968732.48 5968749.00 5968826.23 5968832.37 5968932.15 5969031.93 5969105.40 5969131.72 5969149.00 5969231.63 5969331.54 5969431.45 5969531.36 5969631.27 5969731.18 5969777.00 554811.91 554811.69 554811.47 554811.26 554811.04 554811 .00 554810.93 554810.93 554810.97 554811.00 554811.03 554811.02 554811.00 554810.87 554810.71 554810.55 554810.39 554810.23 554810.07 554810.00 Dogie g [deg/1 OOftl 0.00 0.00 0.00 0.00 0.00 0.00 Vertical ¡ Station Comment Section[f! t] ! I 8081.571 8181.37: 8281.17! 8380.971 8480.771 8497.26: DropfTm 3/100, WS 1 E X5 B-FL T1 S ¡ RVSD031804. 3DS Kick off Point 8574.38! EOC. End of DropfTum 8580.51 ! 8680.131 8779.76! 8853.12 j BldfTm 3/100. End of Hold 8879.40! . 8896.65! EOC. WS 1 E X5 B-FL T1 N RVSD031804, SIC ¡ Kick off Point . 8979.141 9078.89! 9178.641 9278.39 ¡ 9378.141 9477.891 9523.63iTD,4 1/2 Liner Pt., WS 1E X5 B TOE I RVSD021804. End of Hold 3.00 0.00 0.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 All data is in Feet unless othelWise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocòÞhillips ConocoPhillips Alåska, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 6 Wellbore: 1 E-123 Wellpath: 1 E-123 Ver#3 Date Printed: 28-Apr-2004 ,&.. BAKER HUGHES INTEQ Comments MDrftl TV Drftl 300.00 300.00 ~33.33 631.64 i 833.33 824.58 ! 1641.50 1386.40 ¡ 2035.87 1531.00 12633.14 1750.00 : 3462.24 2054.00 13860.43 2200.00 '5036.02 2631.05 5548.26 2822.00 5844.49 2931.99 6297.28 3098.00 6375.48 3126.67 6480.02 3165.00 6575.48 3200.00 6986.73 3344.00 7426.09 3474.12 r- 7526.09 3500.00 ¡ 7644.58 ~- 3530.67 ~674.04 ~__ 3538.00 . 7802.15 3563.00 7902.15 3574.65 7990.87 3579.16 9339.77 3606.00 9366.03 3606.70 11218.07 3669.00 _~333.25 3672.21 12316.53 3694.00 ,12393.85 3697.27 Lfl673.64 3714.77 ! 12717.30 3717.00 ¡ 13345.86 3742.00 Eastfftl O.OOE 26.30E 73.15E 569.09E 901.61 E 1405.22E 2104.31 E 2440.05E 3431.30E 3827.38E 4017.08E 4281.61 E 4327.30E 4388.38E _~44.15E 4636.83E 4727.16E 4733.31 E 4740.60E 4742A~ 4750.42E 4756.74E 4762.38E 4848.28E 4849.95E 4967.74E 4971.66E 4976.03E 4976.47E 4978.42E 4978.69E 4981.85E Northrftl Comment O.OON KOP 12.26N Bid 5/100 34.11N Bid 6/100 265.37N EOC 420.43N Base Permafrost 655.27N Top T-3 981.26N Top K-15 1137.82N 10 3/4 CSG 1600.04N Trn 3/100 1859.81 N Top Uqnu C 2058.53N EOC 2386.38N Top Uqnu B 2443.00N Start 200' Pump Tanqent 2518.69N Top Uqnu A 2587.81 N End 200' Pump Tanqent, BldfTrn 4/100 2919.62N K-13 3327.60N EOC 3423.99N~ West Sak D .3538.21 N Bid 4/100 3566.69N C 3692.03N Top West Sak B 3791.13N 7 5/8 CSG 3879.54N EOC 5225.44N Drop 3/100 5251.63N EOC 7098.88N BldfTrn 3/100 7213.93N EOC 8196.95N DropfTm 3/100 8274.19N EOC 8553.39N BldfTrn 3/100 8596.99N EOC 9225.04N TO, 4 1/2 Liner pt. I Hole Sections Oiameter Start Start Start Start End End End End\n East[ft] Wellbore [inl MOrftl TVOrft] Northrftl EasUftl MOrftl TVOrftl Northrftl 1 3 1/2 0.00 0.00 O.OON O.OOE 3860.43 2200.00 1137.82N 2440.05E 1E-123 97/8 3860.43 2200.00 1137.82N 2440.05E 7902.15 3574.65 3791.13N 4756.74E 1E-123 63/4 7902.15 3574.65 3791.13N 4756.74E 13345.86 3742.00 9225.04N 4981.85E 1 E-123 CasinÇls Name Top Top Top Top Shoe !Shoe Shoe Shoe Wellbore MOrftl TVOrftl Northrftl Eastfftl MOrftl TVOrftl Northrft] EasUftl 10 3/4in Casinq 0.00 0.00 O.OON O.OOE 3860.43 2200.00 1137.82N 2440.05E 1E-123 7 5/8in Casinq 0.00 0.00 O.OON O.OOE 7902.15 3574.65 3791.13N 4756.74E 1E-123 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Ooyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated O'RI GI NAL~ ~" ConocciPhillips ConocoPhillips AlašKa, Inc.,Slot #123 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL 'LiSTING Page 7 Wellbore: 1 E-123 Well path: 1 E-123 Ver#3 Date Printed: 28-Apr-2004 J&íi. BAKER HUGHES INTEQ Targ~ts____.~___ Nam~.____ ~NQJ1bIftL__ EasUftl TVOrftl . Latitude Lonqitude ! Eastinq Northinq Last Revised WS1EX5BTOE! 9225.04N 4981 .85E 3742.00 N70 19 41.2052 W149 33 19.761~ 554810.00 5969777.00 23-0ec-2003 -BVSºQ~tª-p_4_ _.. WS 1 E X5 8596.99N 4978.69E 3717.00 N70 19 35.0285 W149 33 19.866C 554811.00 5969149.00 23-Dec-2003 B-FL T1 N _..IDIßOO~J @~__.~_ ___ ----- WS 1 E X5 8196.95N 4976.03E 3694.00 N70 19 31.0942 W149 33 19.951: 554811.00 5968749.00 23-Dec-2003 B-FL T1 S ¡ RVSD031804 WS 1 E X5 7098.88N 4967.74E 3669.00 N70 19 20.294€ W149 33 20.2141 554810.00 5967651.00 23-Dec-2003 B-MDPT#2 RVSD021804 WS 1 E X5 5225.44N 4848.28E 3606.00 N70 19 1.8706 W149 33 23.736: 554703.00 5965777.00 23-Dec-2003 B-MDPT#1 ! -.-BVSQ02Jª-0.'L ______ _____~~_ WS 1 E X5 0 TOp· 3423.99N 4733.31 E 3500.00 N70 18 44.1542 W149 33 27.123~ 554600.00 5963975.00 23-Dec-2003 ~VSQOJ2_50~ u_, ___ _._ _ ____ --------- -.--------- --- ---------- Surv~ TººtProgram Reference . Survey Name 645540 . Planned 660199 Planned MDrftl TVDrftl Survey Tool 3860.43 2200.00 ISCWSA MWD 7902.15 3574.65 ISCWSA MWD 13345.86 3742.00 ISCWSA MWD Error Model MWD+SAG - ISCWSA - 28 Jari 03 OJH MWD+SAG - ISCWSA - 28 Jari 03 OJH I MWD+MagCorr+SAG - ISCWSA - 28 Jan 03 OJH ----- -- ---~- ---- 660200 , Planned i All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 3.65 degrees Bottom hole distance is 10484.29 Feet on azimuth 28.37 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORJGJNA:.. IZiUI BAKER HUGHES INTEQ Scale 1 cm = 350 ft -700 -0 700 ESTIMATED SURFACE LOCATION: 933' FSL, 630' FEL SEC. 16, T11N, R10E ConocoPhillips Alaska, Inc. Slot: Slot #123 Well: 123 Wellbore: 1E-123 Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ConoccrPhillips Created by: PJanner Date plotted: 28-Apr-2004 Plot reference is 1 E-123. Ref wellpath is 1 E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 1400 2100 East (feet) .> 2800 3500 4200 4900 5600 6300 7000 7700 ; ¡ 1). - 11200 - 10500 9800 9100 8400 7700 7000 6300 ^ . 5600 Z 0 ;¡ ;!: 4900 ""'" (t) (t) ~ 4200 3500 2800 2100 1400 700 (j) (") Q) CD 0 (") 3 II -700 w CJ1 0 ;::þ TD LOCATION: 404' FNL, 908' FEL SEC. 10, T11N, R10E 0E-123L111E-123 TD,4 1/2" Liner Pt. N ¡ TD,4 112" Liner Pl <¡ 0\; "!1J. 01 {l I ~} ~} ,...;~ TOP WEST SAK LOCATION: t 925' FNL, 1169' FEL ì ,.j r SEC. 15, T11N, R10E ~ ~ 70J/. Ì"o,ö ¿... "<Iii] C ì; '\'7$ ê/8ilì!) .1. 0t:> ì: 6';, f>Y ð~ '3 ~OC Þe/J;¡, S/ct 'é1/j-f'k... IfOS/ct S, 8/700 --..or \0 V700 1r..73 ~ I!I1(¡ ~ Ii' O¡) (}Oo- þ~ ~. ro~(%.;'?~ 'lhp 7'ql]g, ì; $~ '91ìt.¡ $p 7'q %, 8% O,ö (J, 'l7rJel]f 1'1] <1/100 7'1'1]3. '91ìt.¡ C V1ao o R:1 :G t N A~l~ . ¡¡:: o d -500 ;d ~,··o (J.: -w- 500 :;2i ~ '1000 ' ~. Mr· c.. CD 1500 C ëü (.) 2000 - ~ ~ CD 2500 :J .... l- I 3000 - V 3500 - 4000 - 4500 ConocoPhillips Alaska, Inc. Ri.. SAKIR IIUGIIIS INTEQ Location: North Slope, Alaska I Field: Kuparuk River Unit I Installation: Pad 1E Slot: Slot #123 Well: 123 Well bore: 1E-123 '---". -.-.---.----------.---., .-----...-.- .-.. ._-----,--~--_._------- --.-----.---.------ -~.- --- I Point Tie on End of Hold End of BuildfTurn End of Build End of Build KOP End of BuildfTurn End of Hold End of BuildfTurn Target WS 1 E X5 D TOP KOP End of Build Target WS 1 E X5 B-MDPT End of DropITurn Target WS 1 E X5 B-MDPT End of Build/Turn Target WS 1 E X5 B-FL T1 End of DropfTurn End of Hold Top K-15 Target WS 1E X5 B-FLT1 ~ 10 3/4in Casing T.D. & Target WS 1E X5 ~\'\Sf~ C "\'\~ 'ò'òpbe 'Ù~~-v. "\o~~ ~ \()()~ ~ 'Ù%~~-v. po. ()() òe9J\ "\0~0'Q be ';;. be· 'ò~~\~ 'òbe 'O~ \~\~~ ^,~e~\ f\() 1~' f(:,OS\e \0 "\ ß\' be\\V \ ,e1-v.~'Q \A\"\'\~ \¡,¡~ · " ~ t' ~\\,)I --...-.>-0>--___ ~ ~() ~\, -"1 ~'(èi. "\ ß~~e ßi,\~~ , f?-v.~'Q ~\'ò\~ C ~()CJ 1 f(:,~ò RKB Elevation: 99' KOP 6.00 Bid 5/100 BId 6/100 32.00 50.00 EOC DLS: 6.00 deg/100ft Base Permafrost -500 0 500 Scale 1 cm = 250 ft u____ . ___ __.__ MD 0.00 300.00 633.33 833.33 1641.50 5036.02 5844.49 6575.48 7426.09 7526.09 7644.58 7990.87 9339.77 9366.03 11218.07 11333.25 12316.53 12393.85 12673.64 12717.30 13345.86 Conoc;Phillips --- '-Creàfeifby:-' Planner . Date plotted: _~2-A~r-2004 Plot refêi'eñCeTs'1E-=-123. Ref well path is 1E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum, Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. ___._ ..___ _ ,~~~~<:~.--ï.~ alig~!~_~.~UE North. _ WELL PROFILE DATA Inc Azi TVD North 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 10.00 65.00 631.64 12.26 20.00 65.00 824.58 34.11 68.49 65.00 1386.40 265.37 68.49 65.00 2631.05 1600.04 68.49 38.90 2931.98 2058.53 68.49 38.90 3200.00 2587.81 75.00 3.65 3474.12 3327.60 75.00 3.65 3500.00 3423.99 75.00 3.65 3530.67 3538.21 88.86 3.65 3579.16 3879.54 88.86 3.65 3606.00 5225.44 88.07 3.65 3606.70 5251.63 88.07 3.65 3669.00 7098.88 88.73 0.25 3672.21 7213.93 88.73 0.25 3694.00 8196.95 86.42 0.40 3697.27 8274.19 86.42 0.40 3714.77 8553.39 87.72 0.29 3717.00 8596.99 87.72 0.29 3742.00 9225.04 East 0.00 0.00 26.30 73.15 569.08 3431.30 4017.08 4444.15 4727.16 4733.31 4740.60 4762.38 4848.28 4849.95 4967.74 4971.66 4976.03 4976.47 4978.42 4978.68 4981.86 deg/10OO 0.00 0.00 3.00 5.00 6.00 0.00 3.00 0.00 4.00 0.00 0.00 4.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 3.00 0.00 --~:------,--_._--------_ . 1.1 ''I. I~;~~;~~l ----·-·-------'~-~----11Y:~~1 ----,-.-- ---.-- - -- V. Sect 0.00 { 0.00 13.91 38.70 301.08 1815.35 2310.23 2865.63 3621.94 3718.53 3832.99 4175.01 5523.65 5549.89 7400.89 7515.95 8497.26 8574.38 8853.12 8896.65 (" 9523.63 1 000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section (feet) -> Azimuth 3.65 with reference 0.00 N, 0.00 E from Slot #123 --.--.-.' ~'--'-'-'-'-- ".-.'.,---,-- '-~-'--'...._~._---~--_.__._.____._.__.__________._._'·~_···___~,____w --...-..----.-..-----.-- -, ---~--"._..,--_..- ----.-.---.--.-.,..--,---.... ~~-" -- ------------- -- -- ----- - .~------ ~----------- ---~.~--------_.__.----_._-- C) ;::0 - G)~ -§ 5;: ~ 3350 r- _ 3400 ... Q) Q) 'I- ~ 3450 ... a. Q) C 3500 Cã (.) t: 3550 Q) > ~ 3600 i... I- . V 3650 =~ S'ð¥. \) - ~es\ _ \o\> 3700 Irttill BAKER HUGHES ........_...._._..._.._-~..._- INTEQ ~ ',Sf,) £¡\Ò Iõ ~ ~'ô-c,e~O\e, \'Ç\'! ~~~ -<\e \0 ~~\~~è \ 'Òø.t(\ð. ~ r) ~\ 'õv ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ~\ ()() £¡\Ò~~9\ ",_.w_·_.'."","'''.,,,..,,,,,,,, ....." «;.00 3650 3700 3750 3800 3850 Seale 1 em = 25 ft C\ ()() 'It 1':)' £¡ '!.. S'ð¥. a..~ 5J() ~es u '\ o\> -..d .... ~ 0'ðS$\Cð Sl'b\(\ 1 ~,,~ ()() ò! S be. 0'0 . 'It «;.00 Slot: Slot #123 Well: 123 Well bore: 1E-123 . ~I \ r;j.) $'(o\> «;.Cß 9'2- .................,............... "... ..,..".,."......................"'...."'.,,-,, 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 Vertical Section (feet) -> Azimuth 3.65 with reference 0.00 N, 0.00 E from Slot #123 "'¡r/' ConocoPhillips Created by: Planner Date plotted: 22-Apr-2004 Plot reference is 1E-123. Ref well path is 1E-123 Ver#3. Coordinates are in feet reference Slot #123, True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. ~ . ··..··w..'.""..""............·.....·..,,'.,. 4500 4550 4600 4650 4700 ....1E-123l1 > 1E-123) 4750 0 :::c: - G: ¢: Il) - ~ z' II ·5 Þ Q) 2750 ~ en r _ 3000 .... CD ~ ~ 3250 .... Co CD C 3500 'is (.) :e 3750 CD > CD 4000 ~ ~ l- I V 4250 r,.. BAKER HUGHES I NTEQ - I ~~~ 1E-123L 1 > \)~O'Q f(;.OV ... .. ^"-.. M"".""'''''MN.M''.''m.w......~"...._...."....." . ,.I,i m.'-.M'_ __, - 11E-123) ~,,~ ~V \)~o9 ~ -e 4500 4500 4750 5000 5250 5500 Scale 1 em = 125 ft ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #123 Well: 123 Well bore: 1 E-123 Conoc6PhilIi pS Created by : Planner Date plotted: 22-Apr-2004 Plot reference is 1 E-123. Ref wellpath Is 1 E-123 Ver#3. Coordinates are in feet reference Slot #123. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft, Plot North is aligned to TRUE North. ..." ( ( ~?\. ,?>I'\':P ,,\'2- \>.f\ß r.~~ _.t';~__io'1'E-'23L11 .. 1'1 1t.,. ",I,\r$) 'Y;.OV 00 <:.OV 11E-123\ t<'«\ J '!J\"I v 'O~o'Q' ' '?).?f. <" ~ '?\. ,,\'2- \>.f\ß iO,bc ,v w.w."............,..,""".,,,,,,,.,..,,,,.....,,,....,.............,. 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 Vertical Section (feet) -> Azimuth 3.65 with reference 0.00 N, 0.00 E from Slot #123 '!J\,\<;j) 'õ~<"lðlð~~ OV . ...."" ...,,, ...-...-.....-'''----,-.....-..-----.....-..".,,-..----....-..............",-5:.... ,W'N. 1t 11'1 'Y.'\oo 1ð1ð~f(;.OV 'õ'({.\<" 8750 9000 9250 9500 9750 10000 --~--- Ri. BAKIR HUGHIS -- INTEQ ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E Slot: Slot #123 Well: 123 Well bore: 1 E-123 ConocÓPt,illips TRUE NORTH Created by : Planner Date plotted: 22-Apr-2004 Plot reference is 1 E-123, Ref well path is 1E-123 Ver#3, i Coordinates are in feet reference Slot #123. i True Vertical Depths are reference Rig Datum, Measured Depths are reference Rig Datum, Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft Plot North is aligned to TRUE North. 350 o 10 f~\'310 ~ + 20 30 40 50 60 70 80 120 ¡ 80 110 200 240 [ I I I J 90 ! 100 110 120 130 140 150 1900 160 170 340 320·- . 700 330 300 300 ~/ 290 ~í í I~' / ~"I \ -] 2V!; ! ' I < 270 1240 200 16Q ..120 80 C~ll·.·~iða¡jÕj~~~-~\ 01 ~\ y'\ 2~ \ \ \ \ .. \ ......11 ~.. \. I I \ . \ '\ \ . '~\\ \ 250 \ \ \ % ~ ¡~.¿' \ ~230 220 ~\~,100.,' '700 ~. 300 210 200 300 190 . 180 11 00.· . . 300 /700 I~\ ~ 4\\····· ~rmal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well C!!@ ORIGINAL '1:taker Hughes Incorporatén Anticollision Report Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1 E Reference Well: 123 Reference Wellpath: 1 E -123 Summary < Offset Wellpath > Site Well Wellpath Pad 1 E 170 170 D-Lateral VO Plan: 275.00 275.00 1180.24 4.26 1175.98 Pass: Major Risk Pad 1 E 17 1 E-17 VO 340.02 350.00 752.62 5.30 747.32 Pass: Major Risk Pad 1 E 18 1E-18 VO 1107.91 1075.00 533.37 25.57 507.81 Pass: Major Risk Pad 1 E 19 1 E-19 VO 1074.47 1050.00 590.83 24.23 566.60 Pass: Major Risk Pad 1 E 20 1 E-20 VO 1206.63 1200.00 648.72 30.05 618.68 Pass: Major Risk Pad 1 E 21 1 E-21 VO 1008.56 1000.00 704.19 21.79 682.40 Pass: Major Risk Pad 1 E 2 1 E-02 VO 365.56 375.00 640.11 5.77 634.34 Pass: Major Risk Pad 1 E 22 1 E-22 VO 483.77 475.00 762.72 8.00 754.72 Pass: Major Risk Pad 1 E 23 1 E-23 VO 759.96 750.00 807.97 14.14 793.83 Pass: Major Risk Pad 1 E 24 1 E-24 VO 977 .40 975.00 678.92 20.72 658.20 Pass: Major Risk Pad 1 E 24 1 E-24A VO 977 .48 975.00 678.95 20.72 658.22 Pass: Major Risk Pad 1 E 25 1 E-25 VO 836.71 850.00 919.14 16.21 902.94 Pass: Major Risk Pad 1 E 26 1 E-26 VO 572.11 575.00 971.18 9.80 961.39 Pass: Major Risk Pad 1 E 26 1 E-26A VO 572.11 575.00 971.18 9.80 961.39 Pass: Major Risk Pad 1 E 27 1 E-27 VO 358.64 375.00 1240.98 5.65 1235.33 Pass: Major Risk Pad 1 E 28 1E-28 VO 379.91 400.00 1120.11 6.05 1114.06 Pass: Major Risk Pad 1 E 29 1E-29 VO 361.12 375.00 1000.91 5.70 995.21 Pass: Major Risk Pad 1 E 30 1 E-30 VO 362.58 375.00 880.94 5.72 875.22 Pass: Major Risk Pad 1 E 31 1 E-31 V1 342.69 350.00 424.51 5.54 418.97 Pass: Major Risk Pad 1 E 31 1E-31PB1 VO 342.69 350.00 424.51 5.54 418.97 Pass: Major Risk Pad 1 E 3 1E-03 V1 367.13 375.00 520.02 5.80 514.22 Pass: Major Risk Pad 1 E 32 1E-32 VO 275.00 275.00 765.42 4.07 761.35 Pass: Major Risk Pad 1 E 33 1 E-33 VO 552.21 550.00 904.73 10.04 894.69 Pass: Major Risk Pad 1 E 33 1 E-33PB 1 VO 552.21 550.00 904.73 10.04 894.69 Pass: Major Risk Pad 1 E 34 1 E-34 VO 370.22 375.00 299.69 6.06 293.63 Pass: Major Risk Pad 1 E 35 1 E-35 VO 249.99 250.00 896.63 3.61 893.02 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 249.99 250.00 896.63 3.61 893.02 Pass: Major Risk Pad 1 E 36 1 E-36 VO 274.99 275.00 203.16 4.11 199.05 Pass: Major Risk Pad 1 E 4 1E-04 VO 391.69 400.00 399.65 6.26 393.39 Pass: Major Risk Pad 1 E 5 1 E-05 VO 440.93 450.00 284.00 7.20 276.81 Pass: Major Risk Pad 1 E 6 1E-06 VO 420.47 425.00 159.16 6.80 152.36 Pass: Major Risk Pad 1 E 7 1 E-07 VO 399.00 400.00 41.27 6.39 34.88 Pass: Major Risk Pad 1 E 8 1 E-08 V1 725.30 725.00 67.44 13.19 54.25 Pass: Major Risk Pad 1 E 9 1 E-09 VO 445.03 450.00 291.74 7.26 284.49 Pass: Major Risk Pad 1 E WSR#2 WS2 V1 2004.42 1650.00 3087.42 81.88 3005.54 Pass: Major Risk ORIGINAL .daker Hughes Incorpora't",d Anticollision Report Company: ConocoPhillips Alaska, Inc. Date: 4/2212004 Tìme: 13:20:56 Page: 1 Field: Kuparuk River Unit Reference Site: Pad 1 E Co-ordinate(NE)· Reference: Well: 123, True North Reference Well: 123 VertiCal (TVD)Refetence: Wellhead(99') 99;0 Reference Wellpath: 1E-123 Db: ... Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 0.00 to 13345.79 ft Scan Method: Trav Cylinder North :\laximum Radius: 5280.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive \Vellpath Date: 1/20/2004 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 0.00 13345.79 Planned: 1E-123 VER#3 V15 MWD+SAG MWD + Sag correction Casing Points MD TVD Diameter Hole Size Name ft ft in in 3860.43 2200.00 10.750 12.250 10 3/4" 7902.15 3574.67 7.625 9.875 75/8" 13345.86 3742.03 4.500 6.750 4 1/2" Summary <-- - --- Offset WeHpath ----> Reference Offset Ctr-Ctr . No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Pad 1 B 101 1B-101V3 13341 .68 6675.00 138.96 48.78 90.17 Pass: Minor 1/200 Pad 1 B 101 1B-101L1 V3 13341.68 6675.00 138.96 No Offset Casings Pad 1 B 101 1B-101PB1 V6 12650.12 3100.00 3327.91 0.00 3327.91 Pass: Minor 1/200 Pad 1 E 10 1E-10VO 394.24 400.00 209.04 6.30 202.74 Pass: Major Risk Pad 1 E 102 102 B-Lateral VO Plan: 2205.04 2175.00 228.96 33.38 195.58 Pass: Minor 1/200 Pad 1 E 102 102 D-Lateral VO Plan: 2250.22 2225.00 227.78 No Offset Casings Pad 1 E 103 103 VO Plan: 1E-103 VE 3804.20 3750.00 400.27 181.52 218.75 Pass: Major Risk Pad 1 E 104 104 VO Plan: 1E-104 VE 870.58 825.00 645.44 18.28 627.16 Pass: Major Risk Pad 1 E 105 105 A2-Lateral VO Plan 461.83 450.00 679.53 8.31 671.21 Pass: Major Risk Pad 1 E 105 105 B-Lateral VO Plan: 461.83 450.00 679.53 8.20 671.32 Pass: Major Risk Pad 1 E 105 105 D-Lateral VO Plan: 461.83 450.00 679.53 8.20 671.32 Pass: Major Risk Pad 1 E 11 1E-11 VO 346.01 350.00 178.58 5.40 173.18 Pass: Major Risk Pad 1 E 112 112 A2-Lateral VO Plan 606.46 600.00 845.76 11.32 834.44 Pass: Major Risk Pad 1 E 112 112 B-Lateral VO Plan: 606.46 600.00 845.76 11.32 834.44 Pass: Major Risk Pad 1 E 112 112 D-Lateral VO Plan: 606.46 600.00 845.76 11.32 834.44 Pass: Major Risk Pad 1 E 114 114 A2-Lateral VO Plan 8213.55 11630.91 1072.25 407.12 665.13 Pass: Major Risk Pad 1 E 114 114 B-Lateral VO Plan: 8210.07 11614.38 1049.67 404.85 644.82 Pass: Major Risk Pad 1 E 114 114 D-Lateral VO Plan: 8208.96 11609.03 1048.53 407.92 640.61 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan 300.00 300.00 1007.37 4.71 1002.66 Pass: Major Risk Pad 1 E 117 117 B-Lateral VO Plan: 300.00 300.00 1007.37 4.71 1002.66 Pass: Major Risk Pad 1 E 117 117 D-Lateral VO Plan: 300.00 300.00 1007.37 4.71 1002.66 Pass: Major Risk Pad 1 E 119 119 VO Plan: 1E-119 Ve 300.00 300.00 1043.99 4.70 1039.29 Pass: Major Risk Pad 1 E 1 1 E-01 VO 364.04 375.00 760.37 5.75 754.62 Pass: Major Risk Pad 1 E 1 1 E-01A VO 364.04 375.00 760.37 5.75 754.62 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO Plan: 576.37 575.00 39.01 10.73 28.28 Pass: Major Risk Pad 1 E 121 121 D-Lateral VO Plan: 576.37 575.00 39.01 10.73 28.28 Pass: Major Risk Pad 1 E 12 1 E-12 VO 322.44 325.00 220.61 4.96 215.65 Pass: Major Risk Pad 1 E 123 1E-123 L 1 VO Plan: 1E- 6750.00 6750.00 0.87 412.49 -411.62 FAIL: Major Risk Pad 1 E 126 126 A2-Lateral VO Plan 373.67 375.00 80.73 6.38 74.36 Pass: Major Risk Pad 1 E 126 126 B-Lateral VO Plan: 373.67 375.00 80.73 6.38 74.36 Pass: Major Risk Pad 1 E 126 126 D-Lateral VO Plan: 373.67 375.00 80.73 6.38 74.36 Pass: Major Risk Pad 1 E 13 1E-13VO 343.83 350.00 307.51 5.37 302.14 Pass: Major Risk Pad 1 E 14 1 E-14 VO 364.30 375.00 408.60 5.75 402.84 Pass: Major Risk Pad 1 E 15 1E-15VO 341.84 350.00 522.31 5.33 516.98 Pass: Major Risk Pad 1 E 16 1E-16VO 340.92 350.00 637.36 5.31 632.04 Pass: Major Risk Pad 1 E 166 166 A2-Lateral VO Plan 380.44 400.00 1081.01 6.57 1074.44 Pass: Major Risk Pad 1 E 166 166 B-Lateral VO Plan: 380.44 400.00 1081.01 6.57 1074.44 Pass: Major Risk Pad 1 E 166 166 D-Lateral VO Plan: 380.44 400.00 1081.01 6.57 1074.44 Pass: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 6884.94 11610.27 462.02 62.21 399.81 Pass: Minor 1/200 Pad 1 E 168 168 B-Lateral VO Plan: 6829.41 11595.26 296.55 No Offset Casings Pad 1 E 168 168 D-Lateral VO Plan: 6813.25 11588.28 256.45 No Offset Casings Pad 1E 170 170 A2-Lateral VO Plan 275.00 275.00 1180.24 4.26 1175.98 Pass: Major Risk Pad 1 E 170 170 B-Lateral VO Plan: 275.00 275.00 1180.24 4.26 1175.98 Pass: Major Risk ORIGINAL ~. \.--- ' lE-123 Drillinq Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole /10-3/4" Casino Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Low Low Moderate Moderate Mitigation Strategy Monitor cellar continuously during interval. f/ Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Trip speeds, Proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casino Interval Hazard Running Sands and Gravels Stuck Pi pe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Moderate Low Low Low Moderate Mitiqation Strateqy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, , Decreased mud weight .I BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole I 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate I Mitigation Strategy ,I Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out 1E-123 Drilling Hazards Summary. doc prepared by Steve McKeever 5/1/2004 2:00 PM ORIGINAL Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 4/15/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 108' MD < Base of Permafrost at 2,500' MD (1,701' TVD) < Top of Tail at 3,100' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,900' MD (2,215' TVD) Mark of Schlumberger SC.I_DIP CemCADE Preliminary Job Design 10 3/4" Surface Permit Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,100' MD. Lead Slurry Minimum pump time: 250 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.43 ft3/sk 0.6381 ft31ft x (108') x 1.00 (no excess) = 0.3637 ft3/ft x (2500' - 108') x 3.50 (250% excess) = 0.3637 ft31ft x (3100' - 2500') x 1.35 (35% excess) = 68.9 ft3 + 3044.9 ft3+ 294.6 ft3 = 3408.4 ft3/4.43 ft3/sk = Round up to 770 sks 68.9 ft3 3044.9 ft3 294.6 ft3 3408.4 ft3 769.4 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 170 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft31ft x (3900' - 3100') x 1.35 (35% excess) = 0.5400 ft31ft x 80' ¡Shoe Joint) = 392.8 ft3 + 43.2 ft = 436 ft3/ 2.52 ft3/sk = Round up to 180 sks 392.8 ft3 43.2 ft3 436 ft3 173 sks BHST = 43°F, Estimated BHCT = 62°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry" 7 608 86.9 121.9 T ail Slurry 6 81 13.5 135.4 Drop Top Plug 8.0 143.4 Displacement 7 352 50.3 193.7 Slow Rate 3 15 5.0 198.7 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 20, Ty < 30. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv > 20, Ty > 30 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL SGIII.PI. CemCADE Preliminary Job Design 7.625" Intermediate- Casing Permit Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 4/15/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 60% excess. Tail slurry is designed for 500' MD above upper lateral window. Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/sk 0.2148 ft31ft x 990' x 1.60 (60% excess) = 0.2578 ft31ft x 80' (Shoe Joint) = 340.2 ft3 + 20.6 ft3 = 360.8 ft3/ 2.26 ft3/sk = Round up to 160 sks 340.2 ft3 20.6 ft3 360.8 ft3 159.6 sks Previous Csg. < 103/4",45.5# casing at 3,900' MD BHST = 79°F, Estimated BHCT = 69°F. (BHST calculated using a gradient of 2 .ErF/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 30 6.0 6.0 Drop Bottom Plug 10.0 16.0 MudPUSH II 5 40 8.0 24.0 T ail Slurry 5 64 12.8 36.8 Drop Top Plug 10.0 46.8 Displacement 7 343 49.0 95.8 < Top of Tail at Slow Rate 3 20 6.7 102.5 7,000' MD MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. < 75/8",29.7# casing in 9 7/8" OH Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 20-24, Ty = 22-29 TD at 7,990' MD (3,580' TVD) Centralizers: Recommend 1 Y2 per joint across zones of interest for proper cement placement. ORIGINAL o ~ - C1 - z » I Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT @ +/- 108' MD Wellhead 1 Tubing Head 1 Tree, 13-5/8" x ¿- 4-%",5,000 ksi 1 E-123 As Staked,;, Eastings: +/- 549,890 Northlngs: +/- 5,960,520 Pad Elevation: 71' AMSL - Doyon Rig 141 Rig Floor (RF) @ 0' Elevation: 99' AMSL (x) Joints Tubing Tubing String: 4-1/2", 12.6 #, L-80, IST,AS Modiifed with Special Clearance Couplings (4.920" aD) (x) Joints Tubing -t to -\ ~ e'(~\ A;"'13\. """, '\ 'é." \ s.. i:\\\..... '\ ,\Z3 \ scW~ø. '\Je'l' 3J '\ E." Ufi" ¡ ~\~" - ot'\:í:1\ \O\t'eG~'\ (1) Gas Lift Mandrel Top of Ugnu C @ 5,548' MD 1 2,822' TVD --. (1) ESP Motor 1 Intake Section, bottom at 6550' MD 1 3218' TVD Liners, 4-%", 12.6#, L80, DWC/C, every joint slotted, (0.125" x 2.5" slots, 32 per foot, 5.9% open area), Top of Cement @ 7,000' MD 1 3,348 TVD ~ 1 E-123L 1: 6-%" Upper lateral TD @ 13,340 MD/l 3679 TVD I ~ **$*~)r~~~~~:;~~~~~§~~~~~~:,_§~§§§~~§§§§§§~§§§§§§§§§§§§§§§§§§§§~~§I I 123L 1 Window @ +1- ~ 7,526' MD 13,500' TVD, k'" 75 degrees Top of West Sak@ 7,526' MD /3,500 TVD--' 4- %" slotted liner top @ at +1- 7,566' 1 3510' ;§§§§§§§§§§§§§§§§§§§§§§§§§§§§§§ªªªª§ªª§§§ª§§§§§§§§§§§~§§ ~ , ~ 7-5/8",29.7#, L-80, STCM 1E-123: J ~ Casing set @ +1-7,902' MD 1 6-%" Lower lateral 3,574' TVD TD @ 13,345 MD 1 Set @ 85 degrees TD 9.875" hole 3,742 TVD ~~(!; ~.~ ~ ~~~ ~"5 ~<I) (1)"= sê ~æ ~E ~\f! ( M ('II "I"" WU "1"":;:; -I'll ~~ >,c"l"" CU'l- :8~~ u=E... .gem oo,c ......CI) 0.._ ~'ê Cl)CI) _0.. fI ~ { "'ši1 Q.¡a =« :ë )0- 8 o c: 8 .--"UIIC;l..;lC;U 0Ullal."C; IVI."aUVll1Vl lL-lkJ 0;" lL-lkJ.l..Jl '-' ¡ --- Subject: Corrected Surface location for lE-123 & lE-123LI From: "McKeever, Steve" <Steve.McKeever@conocophiJIips.com> Date: Mon, 10 May 2004 15:43:38 -0800 . To: "Steve Davies. (E-mail)..<steve_davies@admin.state.ak.us> CC: ~'AIlsup.;.Dtake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com> Steve - The discrepancy you found on the permit paperwork for 1E-123 is indeed a mistake. You will find the same discrepancy on the paperwork for 1E-123L1. On the IIpermit Itll documents I inadvertently wrote the surface location for the wrong well. The correct NAD 27 state plane coordinates for 1E-123 and 1E-123L1 are: X = 549,890" Y = 5,960,520. ~The legal descriptions (offsets from section lines) provided with the paperwork is accurate. Please find attached corrected copies of Page 2 for both "Permit Itll documents, with the correction highlighted in yellow. Please replace page 2 in the documents that you have with these pages. «lE-123 PERMIT IT Corrected.pdf» «lE-123L1 PERMIT IT Corrected.pdf» «112 123 126 166 As Staked.pdf» I have also attached a copy of the official "As-Staked" survey for 1E-123, completed by a professional land surveyor. My apologies for the inconvenience, and thanks for spotting this mistake. Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. 700 "G" Street Anchorage, Alaska 99501 steve.mckeever@conocophillps.com office: 907/265-6826 fax: 907/265-1535 pager: 907/275-0369 RECEIVED MAY I 2 2004 Alaska Oil & Gas Cons. Commission Anchorage "One of the reasons people stop learning is that they become less and less willing to risk failure." - John W. Gardner ___.______...m.__.__._____··___________________________ · . . · .' · Content-Description: lE-123 PERMIT IT Corrected.pdf! 1E-123 PERMIT IT Corrected.pdf Content-Type: application/octet-stream · Content-Encoding: base64 - -. ----------------- --------------------------- _ _ _ _ ___ _ _~___....__._n_m___~____ 1E-123L1 PERMIT IT Content-Description: 1E-123L1 PERMIT IT Corrected.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: 112_123_126_166 As 112_123_126_166 As Staked.pdf Content-Type: application/octet-stream Content-Encoding: base64 n______________________..______.._________..____._____-----0-- ..__.___ I of I 5/12/2004 II: 16 AM --- -'-" ;-...... ...", .....................!.. ._......_.._................._ ._......................_.......L.._..............................] ¡ 660 ft. / 660 ft. ~ ¡ '1 ¡ ;" 330 ft. i ¡ ,:,1 / 330 ft. { ,:,1 ,~ !. ¡ ~ ~ Î ¡ -l-·_·~·_·_·_·l·_·_·_·_·_·_·_·_·_·_·_·_·i'_·_·_·_·_·-1_. :' : i: i i :' !: ¡ ~ j ¡ j ~ i 1 L.... ..... .".. ................... j............. ._..................... _._...................._......_..j._.__ _..........................1 , I , · I I . , I I 1B-101L1 top of'''D'' Sand Liner: 1 E-123 L 1: new proposed toe ~ Î / southern most Joint of production in D sand. ! ~ I I I' I~ . l' 360ft. / . ~ ~ ~300 ft. ----:7 ~ 1 ---- 'I - / 181 ft.-7 , ' I I · . 1 I , . I I , . I I · . 1 I · . I I I I ¡........... ~..................... ï········ ...... -.................... .................................... r···..··....····........····....····.. 1 660 ft. / 669 ft. -I' I j 330 ft. .;" 330 ft. I I ~ o·-,_·_·~·_·_·_·_·_·_,_·- to to I I I I 1 ~ i i ¡ I í! . .... - -..... ,..................... -¡-...... ............................. .... ................. ................¡--................................. j I I 1 E-123: proposed toe J / 119 ft. / 710ft. J , t 1 B-101 7-518" ~aSing shoe. southern most point of production in "B" sand. RECEIVED MAY 1 2 2004- Alaska Oil & Gas Cons. COmmlssíorr Anchorage ~ ConocoPhillips Alaska Spacing between 1 E-123 & 18-101 Sheet 1 of 2 prepared by Steve McKeever 1 E-123 Spacing Exception Diagram. vst 5/11/2004 ---- MD 18-101 D Top 6,848.0 18-101 D Window 6,847.0 1B-101L11st Screen 6,939.0 1B-101 B Top 7,315.0 18-101 Casing Shoe 7,387.0 1B-101 1st screen 7,480.0 1E-123 Toe 13,345.9 1E-123L 1 Toe 13,340.1 1E-123L 1 Toe to 18-101 D Top 182 1E-123L1 Toe to 1 B-1 01 D window 181 1E-123L 1 Toe to 1 B-1 01 1st Screen 270 TVD . 3,655.6 3,655.3 . 3,670.5 3,726.0 3,730.2 3,734.4 3,742.0 3,679.0 TVD SS 3,566.6 3,566~3 ·3,581.5. 3,637.3 3,641 ;2 3,645.4 3,643.0 3,580.0 '-' X, NAD 27 ···S54,7ß4·1 5$4:764;1' 554,764~2 554,739;8 554,724.8 554,709.3 554,810.0 554,810.0 Y, NAD 27 . 5;96£Ml5$.4 5,969;952.5· · ·.···5,97Ø,043;()···.··. 5,97.0,411.7 5,970,482.0 5,970,573.6 5,969,777.0 5,969,777.0 1E-123 Toe to 1 B-1 01 B Top 639 1E-123 Toe to 18-101 Casing 710 1E-123 Toe to 1 B-1 01 1st Screen 803 1 B-1 01 L 1 top of "D" Sand Liner: / southern most point of production in / D sand. ~ ___;OOft.~ 119 ft. / / 181 ft.--7 / 360 ft. 1 E-123: proposed toe J/ ( ConocJ:>'hillips Alaska 710ft. J , RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Spacing between 1E-123 & 18-101 t 18-101 7-5/8" casing shoe, southern most point of production in "B" sand. Sheet 2 of 2 prepared by Steve McKeever 1E-123 Spacing Exception Diagram. vst 5/11/2004 REV DA TE BY CK APP DESCRIPTION REV DATE BY CK-"" APP DESCRIPTION ----' "'c ì < \ ) r ,.r--:'> IN f8 .) ~ ,..~ 0 I,. J n::::O O~ 90 ~~8 08 J 110 123- 07 126- 120 ~ 06 130 3485 VICINITY MAP SCALE: 1 ff = 1 MILE N ~~8 04 180 190 150 03 200 210 160 02 220 230 ~2 01 24~ 112 33825 830 260 35 16 15 1190 21 22 029 166- 028 J .J I,. 027 'Y NO SCALE R~ECEIVED MAY 1 2 2004 Alaska Oil & Gas Cons. Commission LEGENDAnchorage o EXISTING CONDUCTORS . NEW CONDUCTOR LOCATION SEE SHEET # 2 FOR NOTES AND LaC A TION INFORMATION AREA: 1 E 5Jl LOUNSBURY & ASSOCIATES. INC. S~YORS ENGINeERS PLANNERS ConocJP'hillips Alaska, Inc. DRAWING NO: 4/09/04 MODULE: XXXX DS1E WELL CONDUCTOR 112, 123, 126, & 166 AS-STAKED LOCATIONS NSK 6.105 - d32 \ PART: 1 OF 2 \ REV: 0 UNIT: 01 CADD FILE NO. LK6105D32 REV DA TE BY CK APP DESCRIPTION REV DA TE BY C~ APP DESCRIPTION NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 3. ALL DISTANCES ARE TRUE. 4. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-E MONUMENTS PER LHD AND ASSOCIATES. 5. DRILL SITE 1-E GRID NORTH IS ROTA TED O· 00' 31" EAST FROM GRID NORTH. 6. DATE OF SURVEY: 2/05, 4/23 & 4/24 2004 Sec. 16, T. 11 N., R. 1 0 E. , UMIA T MERIDIAN Well A.S.P.s LA TITUDE LONGITUDE SEC. SEC. PAD O.G. No. 'y' 'X' LINE LINE ELEV. ELEV. O/S O/S F.S.L. F.E.L. 112 5,959,780.7 550,300.6 70· 18' 03.20" 149· 35' 33.37" 1 91' 226' 66.3 63.1' 123 5,960,519.7 549,889.7 70· 18' 10.49" 149· 35' 45.20" 933' 630' 70.7 65.1' 126 5,960,439.7 549,889.7 70· 18' 09.70" 149· 35' 45.22" 853' 631' 70.8 65.1' Sec. 21, T. 11 N., R. 1 0 E. , UMIA T MERIDIAN Well A.S.P.s LA TITUDE LONGITUDE SEC. SEC. PAD O.G. No. 'y' 'X' LINE LINE ELEV. ELEV. O/S O/S F.N.L. F.E.L. 166 5,959,439.8 549,889.6 70· 17' 59.87" 149· 35' 45.42" 147' 640' 70.4 63.4' RECEIVED MAY 1 2 2004 Alaska Oil & Gas Cans. COßI1ÍSSion Anchorage ø· LOUNSBURY ^ Be ASSOCIATES. INC. ~ S~EYORS ENGINEERS PLANNERS y ConocoPhillips Alaska, Inc. I DRAWING NO: 4/09/04 AREA: 1E MODULE: XXXX UNIT: 01 DS1E WELL CONDUCTOR 112, 123, 126, & 166 AS-STAKED LOCATION NSK 6.105 - d32 I PART: 2 OF 2 I REV: 0 CADD FILE NO. LK6105D32 N ~ SHARON K. ALLSUP-DRAKE 1052 CONOCOPHILLlPS ~~=AK 99501 ,,~ L/J(ti72ð"-/ ",-""" ~6i~ ~~E 5> 7;::1 T~ of¡q L/15/é::{ / tit C(1 C( I $ ~---- t~:.{;: ~¿,,,,,,--jv-e JcJe' !¿[~;; h _./r".ö/; ¿> '~'~-----rrÖ[LARS 0 ....... CHASE Chase ManhaUan Bank USA, N.A. Valid Up To 5000 Dollars "', .,_.."-"'_...."" ç! / .'.0_ ,c}1,Æ .f"'c._~j )). {<t. I: 0 3 1. 1. 0 0 1. L, L, I: 2 1. B L, 7 1. gO 7 g 2 7 bill 1. 0 5 2 ( e UO\SS~O'J vG')?, V c' Q31\\:1" e~se\'J e 'ú',''-.l :;:10 e e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K/2tL- I E- /~ '3 PTD# 'ZdI ".-- c> 7 '-I . ~~v~Jbp¡rl-te trl...f- CHECK WHAT ADD-ONS APPLIES (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" Tbe permit is for a new wellbore segment of existing well Permit No, API No. Production. sbould continue to be reported as a function of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(:1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\temp)ates Tbe 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. (Companv Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. AlJ dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrougb target zones. Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: .KUPARUK RIV U WSAK 1 E-123 Program DEV Well bore seg 0 PTD#: 2040740 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType --ºEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal 0 Administration 1 Permit fee attached. Yes. . - - - - - - - - - - - - - - - 2 .Leasenumbe.r appropriate. . - - ~ - - · . Yes. . 3 .Uni~ue. weltn.ame .aod lJuJl1ber:. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , Yes. , . . . . . ' . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - -- - - - - - - - - - - - - - -- 4 WeJlJo.cated lna.defined POQL . _ Yes · . KRU WestSak Ojl Pool,. Con!>erva.tion Or:.der. No.. 406A . . - - - - 5 WeJI Jocated proper di~tance. fr:.om dri]ling unitb~undary. . . - - - - - - Yes . . . . . NQmioal spa.clng wlthin the pooJ ls.1 0 acres.. . . . . 6 WeJI Jo.cated proper dlstance. fr:.o!n QtheJ wells. . . - - - - · Yes. . . . · Ye.s, 1 E;-123. will Qpeo the poQI 71 Q' from th.esoutheromQst point ~f production.in Qff$etweIl18-J ot 7 ~uffjcient acreaQ.e.ayai1able In.drilJiog unit. . . . Yes · Ye.s, 1E;-123.will Qpeo the POQI jn. a diffeJent 1Q-ªc.re drilllng block. than off$etwell18-10t 8 Jf.deviªted, is.weJlboJe plªtJncluded . . Yes - - - - - - - - - - - - - - - - - - - - - - 9 Operator onl}' affected party. . . . - - - - Yes - - -- - - - -- - - - - - - - 10 .Operator has.approprlate.b.ond inJQrce. . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . , . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . 11 Per:.mitcao be lssued witho.ut conse.rvation orde.r. . . Yes - - - - - - - - - - - - -- - - - - - - - - - - -- - - -- - - - - Appr Date 12 Per:.mitcao be lssu.ed witho.ut administr:.atille.approvaJ . . . - - - - - - · No - - - - - - - - - - - - SFD 5/12/2004 13 Can permit be approved before 15-day wait Yes e 14 WeJI .located within area and .strata authorized by.lojection Order #l (puUO# in. commeots). (FQr. NA. . . . . - - - - -- - - - - - - - - - - -- - - - - - - 15 A!I Wel!s.Within.1l4.mil.e.are.a.of r:.eyiew id.eotlfied (for:. service w.ell olllyL . . . . . . . . . , . . . . NA. . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre.-produçed. iojectQr~ duration of pre-production less. than. 3. months. (For .seryiçe well only) . . .NA. . - - - - - - - - - - - - - - - - 17 ACMP Finding ~f Con~ist.ency .has been .is.sued. forJhís project . . NA. · . Well will be drilled from ªn. existing pad. . . Engineering 18 ~~oduçtor:. str:.ingprovided . . - - - - - - - -- · Yes. . - - - - -- - - - -- - - -- 19 ~urface .cªsillg.PJQtects. all.known USQWs . NA . . . . . . . AllaquifeJs exempted 40 cm 147,102(b)(3), . . 20 CMTvola.dequateto Ci[cul¡;¡te.on.cond~ctor.& SUJrCSg . . .Yes. 21 ~MT vol adequ.atetQ tie-in Jongstril'1g to .surf CS-9. . N.o. - - - - -- 22 .CMT will coyer .all known pro.ductiye hOJilon~. No. . · . slQtted liner ÇQmpJetion pl¡3Ilned. 23 .Casiog de.signs ad.eQuate for. C,.T~ B&.p.ermafrosL . . .Y.es. . . . - - - - - - - - - - - - - 24 Adequ¡lt.e iankage OJ re.$erye pit . . . . .. . · . .Yes. . . . . . . Rig js.e.quippe.dwith steel pits. .No.rese.rv.e.pitplanne.d, All waste toCJass II w.elJ(s), . . 25 Jf.a.re-dr.iII~ tlas.a to:4.03 fOJ ¡lbandQnmenl beeo approved . NA - - - - 26 Adequ¡lt.e .w.ellbore. sepC,lration proposed. . . . . . . . . . , . , . . . . . . . . . . Y~s . . . . . . . Proximity. analysis pe.rfor:.med, Jrayeling ç}'lioc!.er ploUncJu.ded. . GyrQs.p'ossible. . . . . . 27 Jf .diverter required, doe!> it meet reguJations. . . · Yes. . - - -- - - - - - - - - - - - - - - -- Appr Date 28 .DriIJiog fluid.pJQgram sc./lemªtic.&. e.q~ip JisLadequate. . . · . Yes. . . . . . BH~ ral'1ge. 8.1 ~ 9.4 EMW. Planned mud we.ights. 9.0 - 9. Z ppg. . TEM 5/4/2004 29 BOPEs,.do.they meetreguJaiion . . . - - - - - -- · Yes. - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - . 30 .BOPE press ratiog appr:.opr:.iate; .te.st to .(put PSig in.comments). . . Yes · CalcuJatedMASP. t422 psi.. 3500 psi.appropriate, CPAI normally te.stsio 5QOO psi.. . 31 ~hoke.manifQld compJies w/APIRf>-53. (May 54). . . Yes - - - - - - - - - - - - - - - - - 32 Wo.rk will occur:. without .operªtion .shutdown. . - - - - Yes - - - - - - 33 Js. presence. oJ H2S gas. prQbable. . - - - - -- No. . . . . Mud should pr.eclude.H2~.oJuig.. Rigjs equipped. with .sensor:.s.and alarms. . . . 34 MeçhaniCÇIl.condjti~o of wells with.il'! AOR yerified. (fors.el'Vlce well Qnly) NA. - - - - - - - - - - - - - - - - - - - - -- - Geology 35 P~r:.mitc¡;¡o be i~su.ed wlo. hydr.ogens.ulfide meaSur:.es. . . Y.es · KRU W.estSak wells.1/4 mile. to east meªsure.d Jess than 5 ppmH2S jn. August 20Q3, . 36 D¡;¡ta.pre.sented Qn. potential overpres.sure ZOlle!> . .Yes. · . Expected rese.l'\loir preSSUJe is ßJ.- .9.4.ppg EMW; will.be .drilled with 9.0 ~ 9.7 ppg mud. Appr Date 37 Sei~mlcanªlysjs. Qf !>haJlow gas.zooes. . . . . . . . . . NA. · l:Iydraie.s.and shaJlow gas are not expected. SFD 5/10/2004 38 Seªbed .col'!ditioo survey (if Qff-shor:.e) . . NA. . - - - - 39 . Co.ntact n.am.elphoneJorweekly progress.reports [e1.CpIQrªtoryonlyl . . . NA. Geologic Date: Engineering Date ~~;íSr Commissioner: Commissioner [j~ 61 JG] 1-- e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 04/10/06 AWS 01 **** TAPE HEADER **** LDWG 04/10/07 01 *** LIS COMMENT RECORD *** e e ~() '1- [)1cf 11 J^- ìe,. ) RECEIVED n(" (ì Q 0"0 A \~j V ¡ (,J I.] LV Ll Alaska Oíì & Gas COns. WîIÎ¡~or AncheJrage !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! !!! ! !! !! !! !! !! !!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 5 C. WONG F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1E-123PB1 500292320870 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 07-0CT-04 MWD RUN 6 6 S. TUFTON M. THORTON MWD RUN 16 llN 10E 98.80 70.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 7.625 3694.0 8042.0 12132.0 13.500 9.875 6.750 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 10.491" LONG: W149 DEG 35' 45.223" LOG MEASURED FROM D.F. AT 98.8 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 through 4 utilized a Directional Only service from 105 - 3705 feet MD (105 - 2210 TVD). (2) Baker Hughes INTEQ run 5 utilized an AutoTrak RCLS (RotaryClosed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, and Modular Annular Pressure (MAP) services from 3705 - 8047 feet MD (2210 - 3574 TVD). (3) Baker Hughes INTEQ run 6 utilized Multiple Propagation Resistivity (MPR) with Gamma Ray and Modular Annular Pressure (MAP) from 8047 - 12132 feet MD (3574 - 3608 TVD). (4) Drilling was halted at 12132 feet MD (3608' TVD) to sidetrack. REMARKS: (1) Depth of 10 3/4" Casing Shoe - Logger: 3694 feet MD (2206 TVD) Depth of 10 3/4" Casing Shoe - Driller: 3693 feet MD (2206 TVD) (2) Depth of 7 5/8" Casing Shoe - Logger: 8040 feet MD (3574 TVD) Depth of 7 5/8" Casing Shoe - Driller: 8042 feet MD (3574 TVD) * Please note: Due to the change in resistivity tool type from RNT to MPR at the 7 5/8" casing point, the presentation goes from 2 curves (RPD & RPS from surface to 8040 MD) to 4 curves (RPD, RPM, RPS, & RPX from 8040 MD to TD). (3) A sidetrack was initiated at 11950 feet MD (3650 TVD) (lE-123). (4) The interval from 12102 to 12132 feet MD (3607 - 3608 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 87 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER e e FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3694.0 STOP DEPTH 12132.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ * MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 3694.0 8030.0 MERGE BASE 8030.0 12132.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-123pbl 5.xtf 150 ConocoPhillips Alaska, Inc. lE-123PBl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 e e FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 603 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3694.000000 12132.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 646 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 3650.0 STOP DEPTH 8030.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 22-MAY-04 MSB 18655 e 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: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. RESIST. GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: e 6.75 ATK MEMORY 8047.0 3650.0 8030.0 o 3.8 71. 4 TOOL NUMBER ACE 29649 RNT 1060 RNT 1060 9.875 3693.0 LSND 9.00 .0 .0 100 .0 .000 .000 .000 .000 102.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 5). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-123pb1.xtf LCC 150 e e CN WN FN COUN STAT ConocoPhillips Alaska, I lE-123PB1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 626 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3650.000000 8030.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 3 716 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes e **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 e log header data for each bit run in separate files. 3 .2500 START DEPTH 8030.0 STOP DEPTH 12132.0 # 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: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 28-MAY-04 MSB 18655 4.75 MPR MEMORY 12132.0 8030.0 12132.0 o 84.3 92.2 TOOL NUMBER SDS 7175 MPR 1033 SRIG 60365 6.750 8042.0 FLOW PRO 9.55 .0 .0 33000 .0 .000 .000 .000 .000 96.0 .0 .0 .0 e e MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 6). GR/MPR. Drilling was halted at 12132 feet MD (3608' TVD) on this run to sidetrack. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-123pbl.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-123PBl FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes e e Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 864 Tape File start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8030.000000 12132.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 965 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/10/07 01 **** REEL TRAILER **** LDWG 04/10/06 AWS 01 ~ Tape Subfile: 5 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes **** REEL HEADER **** LDWG 04/09/11 AWS 01 **** TAPE HEADER **** LDWG 04/09/10 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!! !I!!!!! TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION ~ATE: # JOB DATA JOB NUMBER: LOGGING ENG:NEER: OPERATOR WI~NESS: e e LDWG File Version 1.000 Extract File: LISTAPE.HED MWD RUN 5 5 C. WONG F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECJRD 1ST STRING 2ND STRING 3RD STRING PRODUCTION S~RING # REMARKS: 1E-123 500292320800 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 10-SEP-04 MWD RUN 6 6 S. TUFTON M. THORTON MWD RUN 16 11N 10E 98.80 70.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 7.625 3694.0 8042.0 13460.0 13.500 9.875 6.750 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE c:?oC¡ -0 7f ji/J.-1 ¡( REceiVED SEP 2 . 2004 ¡J':I~l(a Oìl& Gas Cons. eomm_ Anchorage e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 10.491" LONG: W149 DEG 35' 45.223" LOG MEASURED FROM D.F. AT 98.8 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 through 4 utilized a Directional Only service from 105 - 3705 feet MD (105 - 2210 TVD). (2) Baker Hughes INTEQ run 5 utilized an AutoTrak RCLS (RotaryClosed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, and Modular Annular Pressure (MAP) services from 3705 - 8047 feet MD (2210 - 3574 TVD). (3) Baker Hughes INTEQ run 6 utilized Multiple Propagation Resistivity (MPR) with Gamma Ray and Modular Annular Pressure (MAP) from 8047 - 13460 feet MD (3574 - 3705 TVD). REMARKS: (1) Depth of 10 3/4" Casing Shoe - Logger: 3694 feet MD (2206 TVD) Depth of 10 3/4" Casing Shoe - Driller: 3693 feet MD (2206 TVD) (2) Depth of 7 5/8" Casing Shoe - Logger: 8040 feet MD (3574 TVD) Depth of 7 5/8" Casing Shoe - Driller: 8042 feet MD (3574 TVD) * Please note: Due to the change in resistivity tool type from RNT to MPR at the 7 5/8" casing point, the presentation goes from 2 curves (RPD & RPS from surface to 8040 MD) to 4 curves (RPD, RPM, RPS, & RPX from 8040 MD to TO) . (3) A sidetrack was initiated at 11950 feet MD (3650 TVD) (lE-123PB1). (4) The interval from 13430 to 13460 feet MD (3705 - 3705 TVD) was not logged due to sensor-bit offset at TO. $ Tape Subfile: 1 85 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOOl.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD e e Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ and clipped curves; all bit runs merged. .5000 START DEPTH 3694.0 STOP DEPTH 13460.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 3694.0 8030.0 MERGE BASE 8030.0 13460.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-123 5.xtf 150 ConocoPhillips Alaska, Inc. lE-123 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= O) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F e e ONE DEPTH PER FRAME Tape depth 10: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 698 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3694.000000 13460.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 741 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 3650.0 STOP DEPTH 8030.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 22-MAY-04 MSB 18655 6.75 ATK MEMORY e TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. RESIST. GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # e 8047.0 3650.0 8030.0 o 3.8 71.4 TOOL NUMBER ACE 29649 RNT 1060 RNT 1060 9.875 3693.0 LSND 9.00 .0 .0 100 .0 .000 .000 .000 .000 102.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 5). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-123.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-123 e e FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 626 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3650.000000 8030.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 716 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes e **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 e log header data for each bit run in separate files. 3 .2500 START DEPTH 8030.0 STOP DEPTH 13460.0 # 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: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 28-MAY-04 MSB 18655 4.75 MPR MEMORY 13460.0 8030.0 13460.0 o 84.3 92.2 TOOL NUMBER SDS 7175 MPR 1033 SRIG 60365 6.750 8042.0 FLOW PRO 9.55 .0 .0 33000 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 e e .000 # HOLE CORRECTION (IN): .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # o BIT RUN 3 (MWD Run 6). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-123.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-123 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 e e One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1144 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8030.000000 13460.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1243 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/09/10 01 **** REEL TRAILER **** LDWG 04/09/11 AWS 01 ., t, a- Tape Subfile: 5 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes