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Home My WebLink About201-038MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD1-14 COLVILLE RIV UNIT CD1-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 CD1-14 50-103-20371-00-00 201-038-0 G SPT 6666 2010380 1666 3832 3833 3833 3833 672 675 674 674 4YRTST P Josh Hunt 6/17/2025 Good test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD1-14 Inspection Date: Tubing OA Packer Depth 1250 2000 1955 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250618073822 BBL Pumped:1.5 BBL Returned:1.5 Thursday, July 24, 2025 Page 1 of 1           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y Samantha Carlisle at 8:05 pm, Apr 26, 2022 'LJLWDOO\VLJQHGE\*UHJ+REEV '12 :HOOV&1 *UHJ+REEV ( JUHJVKREEV#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ *UHJ+REEV QRQH; 6)'97/ '65 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.28 14:50:55 -08'00' RBDMS SJC 050422 32%2; $1&+25$*($/$6.$ $SULO $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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rom:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CRU Well CD1-14 (PTD#201-038) Monitoring Date:Thursday, November 18, 2021 10:43:44 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, November 1, 2021 4:58 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU Well CD1-14 (PTD#201-038) Monitoring Chris— CRU well CD1-14 (PTD#201-038) recently completed a successful 30-day monitoring period on gas injection. This monitoring period was to verify if a high sealibility dummy valve set in the well’s gas lift mandrel had addressed an IA pressurization issue. The IA pressure did not exhibit anomalous behavior during this monitoring period, and our intent is to return the well to normal status. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CRU Well CD1-14 (PTD#201-038) IA Pressurization Date:Thursday, September 2, 2021 8:20:29 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, September 1, 2021 3:24 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1-14 (PTD#201-038) IA Pressurization Chris— An update on the status of CRU Well CD1-14 (PTD#201-038). The IA appears to be back on the same pressurization trend as prior to our diagnostics and troubleshooting. We are considering this a failure of the monitoring period, and the well has been shut-in awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Thursday, August 26, 2021 4:48 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1-14 (PTD#201-038) IA Pressurization Chris— Diagnostics were performed on CRU Well CD1-14 (PTD#201-038) earlier today. Indications of pressure and fluid communication at the lower body seal indicate that it may have been the source of TxIA communication. The tubing lockdown screws were re-torqued in an effort to address this communication path. A subsequent tubing packoff test passed, as well as a subsequent diagnostic MIT-IA. While these are positive indications, we cannot be certain the issue has been resolved since this exhibits a low leak rate. We intend to have the well remain on gas injection service for a 30-day monitoring period to confirm if pressure integrity has been restored. If a pressure communication issue is identified, the well will be shut-in. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, August 25, 2021 4:09 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1-14 (PTD#201-038) IA Pressurization Chris— CRU Well CD1-14 (PTD#201-038) was recently brought on injection for a monitoring period. The IA pressure continued to increase after the rate and temperature had stabilized. In order to verify the increasing pressure was not a lagging thermal response, the IA was bled yesterday. The pressure increase has continued at the same trend. Our intent going forward is to perform DHD diagnostic testing, including an MITIA and wellhead testing, with the well still on gas injection. We will perform this testing at the earliest opportunity and then the well will be shut-in and freeze protected awaiting a path forward. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Monday, August 16, 2021 1:27 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1-14 (PTD#201-038) IA Pressurization Chris— An update on CRU Well CD1-14 (PTD#201-038). The well was used for fuel gas supply during the Alpine facility turnaround and the IA behaved normally. Regarding gas injection service there is still uncertainty if the high IA pressures were a result of thermal and rate effects, or signs of a communication issue while on gas injection. Our intent is to monitor the well on gas injection for 30 days and observe for signs of IA pressurization. During this time, we will also conduct standard diagnostics on the well. We will notify you if any problems are found during these diagnostics and monitoring. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Monday, June 21, 2021 5:05 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com> Subject: CRU Well CD1-14 (PTD#201-038) IA Pressurization Chris— CRU Well CD1-14 (PTD#201-038), the Alpine black start fuel gas well, was observed with high IA pressure. The well will be shut-in from injection service as soon as possible. Alpine has a plant turnaround upcoming in the near future, beginning on or around July 9. It is our intent to still use the well in fuel gas production if needed during the turnaround, but not for further injection service. Diagnostics work will be forthcoming. Attached is a well schematic and a 90-day TIO plot. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com 1 Carlisle, Samantha J (CED) From:Wallace, Chris D (CED) Sent:Monday, August 30, 2021 7:01 AM To:AOGCC Records (CED sponsored) Subject:FW: CRU Well CD1-14 (PTD#201-038) IA Pressurization From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Thursday, August 26, 2021 4:48 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— Diagnostics were performed on CRU Well CD1‐14 (PTD#201‐038) earlier today. Indications of pressure and fluid communication at the lower body seal indicate that it may have been the source of TxIA communication. The tubing lockdown screws were re‐torqued in an effort to address this communication path. A subsequent tubing packoff test passed, as well as a subsequent diagnostic MIT‐IA. While these are positive indications, we cannot be certain the issue has been resolved since this exhibits a low leak rate. We intend to have the well remain on gas injection service for a 30‐day monitoring period to confirm if pressure integrity has been restored. If a pressure communication issue is identified, the well will be shut‐in. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, August 25, 2021 4:09 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— CRU Well CD1‐14 (PTD#201‐038) was recently brought on injection for a monitoring period. The IA pressure continued to increase after the rate and temperature had stabilized. In order to verify the increasing pressure was not a lagging thermal response, the IA was bled yesterday. The pressure increase has continued at the same trend. Our intent going forward is to perform DHD diagnostic testing, including an MITIA and wellhead testing, with the well still on gas injection. We will perform this testing at the earliest opportunity and then the well will be shut‐in and freeze protected awaiting a path forward. Please let me know if you have any questions or disagree with the plan. 2 Thanks, Travis From: Smith, Travis T Sent: Monday, August 16, 2021 1:27 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— An update on CRU Well CD1‐14 (PTD#201‐038). The well was used for fuel gas supply during the Alpine facility turnaround and the IA behaved normally. Regarding gas injection service there is still uncertainty if the high IA pressures were a result of thermal and rate effects, or signs of a communication issue while on gas injection. Our intent is to monitor the well on gas injection for 30 days and observe for signs of IA pressurization. During this time, we will also conduct standard diagnostics on the well. We will notify you if any problems are found during these diagnostics and monitoring. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Monday, June 21, 2021 5:05 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com> Subject: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— CRU Well CD1‐14 (PTD#201‐038), the Alpine black start fuel gas well, was observed with high IA pressure. The well will be shut‐in from injection service as soon as possible. Alpine has a plant turnaround upcoming in the near future, beginning on or around July 9. It is our intent to still use the well in fuel gas production if needed during the turnaround, but not for further injection service. Diagnostics work will be forthcoming. Attached is a well schematic and a 90‐day TIO plot. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907‐670‐4014 Travis.T.Smith@conocophillips.com 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, August 17, 2021 7:54 AM To:AOGCC Records (CED sponsored) Subject:FW: CRU Well CD1-14 (PTD#201-038) IA Pressurization From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, August 16, 2021 1:27 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— An update on CRU Well CD1‐14 (PTD#201‐038). The well was used for fuel gas supply during the Alpine facility turnaround and the IA behaved normally. Regarding gas injection service there is still uncertainty if the high IA pressures were a result of thermal and rate effects, or signs of a communication issue while on gas injection. Our intent is to monitor the well on gas injection for 30 days and observe for signs of IA pressurization. During this time, we will also conduct standard diagnostics on the well. We will notify you if any problems are found during these diagnostics and monitoring. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Monday, June 21, 2021 5:05 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com> Subject: CRU Well CD1‐14 (PTD#201‐038) IA Pressurization Chris— CRU Well CD1‐14 (PTD#201‐038), the Alpine black start fuel gas well, was observed with high IA pressure. The well will be shut‐in from injection service as soon as possible. Alpine has a plant turnaround upcoming in the near future, beginning on or around July 9. It is our intent to still use the well in fuel gas production if needed during the turnaround, but not for further injection service. Diagnostics work will be forthcoming. Attached is a well schematic and a 90‐day TIO plot. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907‐670‐4014 Travis.T.Smith@conocophillips.com Wallace, Chris D (CED) From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Monday, June 21, 2021 5:05 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C; Simek, Jill Subject: CRU Well CD1-14 (PTD#201-038) IA Pressurization Attachments: CD1-14.pdf; CD1-14 90 -day TIO.pdf Chris— CRU Well CD1-14 (PTD#201-038), the Alpine black start fuel gas well, was observed with high IA pressure. The well will be shut-in from injection service as soon as possible. Alpine has a plant turnaround upcoming in the near future, beginning on or around July 9. It is our intent to still use the well in fuel gas production if needed during the turnaround, but not for further injection service. Diagnostics work will be forthcoming. Attached is a well schematic and a 90 -day TIO plot. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com MEMORANDUM TO: Jim Regg P.I. Supervisor�� FROM: Lou Laubensteln Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CDI-14 COLVIL.LE RIV UNIT CDI-14 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name COLVILLE RIV UNIT CDI-14 API Well Number 50-103-20371-00-00 Inspector Name: Lou Laubenstein Permit Number: 201-038-0 Inspection Date: 6/12/2021 Insp Num: mitL,OL210612160320 Rel Insp Num: Thursday, .lune 17, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CDI-14 Type Inj G -TVD 666-_ - , Tubing 3820 g 3820 3820 _ 3820 ' - - - PTD 2010380 Type Test SPT' Test psi 1666 A 1660 2500 2450 2445, BBL Pumped: LS -IBBL Returned: I.5 - QA 927 - 929 _ 929 - L92 Interval 4vRTST PIF - P Notes: Thursday, .lune 17, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg p e DATE: Monday, July 29, 2019 pppp ��F� t 1q P.I. Supervisor z�q SUBJECT: Mechanical Integrity Tests ll( ConocoPhillips Alaska, lac. CDI-14 FROM: Lou Laubenstein COLVILLE RIV UNIT CDI-14 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supryisp— NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CDI-14 Insp Num: mitLOL190724131334 Rel Insp Num: API Well Number 50-103-20371-00-00 Inspector Name: Lou Laubenstein Permit Number: 201-038-0 Inspection Date: 7/24/2019 Packer Depth Well CDI-14 Type Inj c, TVD 6666 - Tubing PTD 2010380 Type Test s1'T Test psi 1666 IA BBL Pumped: i 1.6 BBL Returned: 1.5 OA Interval INITAL P/F P Notes: MIT -IA post rig workover per Sundry # 318-553 v Pretest Initial 15 Min 30 Min 45 Min 60 Min 3320 - 3320 3320 3320 - 1540 1500 - 2460 , 2460 912 - 914 , 914 - 914' Monday, July 29, 2019 Page 1 of 1 WELL LOG TRANSMITTAL #905538590 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: CD1-14 Run Date: 3/9/2019 20 1030 30 73 4 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CDI-14 Digital Data, Digital Log Image file, 3D viewers, and Interpretation Report 1 CD Rom 50-103-20371-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A CUP Y Ur i rnr, TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com RECEIVED Signed: MAY 0 8 2019 AOGCC f%C`1UC11V CLJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 17 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑� i ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ After Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well 121 Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Con000Phillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory ❑ Service [] 201.038 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20371-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: CRL) CD1-14 AL 25559, ADL 25560, ADL 327095 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 18,939 feet Plugs measured None feet true vertical 6,814 feet Junk measured None feet Effective Depth measured 18,939 feet Packer measured 13294, 13365 feet true vertical 6,814 feet true vertical 6634, 6666 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 115' MD 115' TVD SURFACE 3,550 feet 9 5/8 " 3,587' MD 2366' TVD INTERMEDIATE 14,039 feet 7 14,073' MD 6855' TVD OPEN HOLE 4,866 feet 6 1/8 " 18,939' MD 6813' TVD Perforation depth: Measured depth: N/A feet True Vertical depth: N/A feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 13,420' MD 6,690' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER PREMIER PACKER 13,294' MD 6,634' TVD PACKER - BAKER S-3 PACKER 13,365' MD 6,666' TVD SSSV - CAMCO TRM-4E SSSV 2,324' MD 1,842' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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: WA N/A N/A NIA N/A Subsequent to operation: 1 N/A N/A NIA NIA N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service O Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 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: 318-553 Contact Name: Dusty Ward Authorized Name: DustyWard Contact Email: Dusty.Ward@cop.com Authorized Title: Sr. Wells Engineer ..� Authorized Signature: (it/ ` r Contact Phone: (907) 265-6531 � I T' ��I q1 Date: Form 10-404 Revised 4/2017 (/j"Lg!/q`/, y`�� AMMS�APR 1 g 2018 Submit Original Only CiinocoPhillips Alaska, inn. WNS INJ WELLNAME CD1-14 WELLBORE CD1-14 Cm-te.avmtsecea3nu Last Tag Wrmluiem•m nr'vp Annderbn GepM (Poral Em Dam WeNWx urt MM BY Last TaO SLM 13A20.0 2/142018 CD1-14 bcehmbh Last Rev Reason Wpar, 3f.9 gnnoG[ion FiM Doh Wellpme laslMWey Rev Reason: Post Re Wellwvrk CD1-14 lciaylg Casing Strings awing Desed,11n Do (IN WordTop MET set Depth(XRB) Set DepM(NDIpamen (l.. Grade Top Th. CONDUCTOR 16 1506 37.0 1150 115.0 62.58 H40 WELDED Culnp Ift-ipNon OD In) to(In) Top MKS) set DepM often sN DepM TWO)-. widen p_.Graae Top Ties! CONDUCTOR; 3Y.0415DIndun SURFACE 959 8.92 36.8 3,586.5 2,3660 6000 LSO BTG -MGD open Deaarlparn Do ID Nn) Top(XKBI ser 0eptn mKBl SM Dpth Filial... l... II Gni Top TXrmd INTERMEDIATE ] 628 346 14,0]3.1 6.855.1 2600 L-80 BTCM caaMp Deaangwn oo (In;; IDPnI ."mad set o•vtn lnl<el sat over f1v0)... wuLen ll... Gna Trips mu. De NiPPY:1ARsOPEN HOLE 6118 14,073.0 189390 6,813] Poluslagpis 2,321. -Tubing Strings Tubing description z41nq itis... ID lin) ToPlflKq) $¢I Dep[n (X., ael pep" T"Re I... W(11MN Gale Top ConneCNon Tqsssv 2D24145"Completion 4112 Pmdacoon 3.96 34.3 13,350.5 6.659.5 12.60 L-80 MYd 563 Completion Details Top mD) ropm¢I NnmMal "Jorkal poked I.I Item Des Com Senn 34.3 343 012 Hanger FMCHorimmal Gen111"x4-12' IDbing hanger drifted 3.885" 3.958 2,319.5 1,840.2 6563 DB Nipple Campo 4-12"x3.8]5" DBS landing nipple 3875 2.321.0 1,840.8 6564 Pored Nipple Campo 4-112-DCIN-I1 Chemical Intended nipple 3.883 SURFPCE:W8,s5%5- 2,324.1 1,842.1 65.67 TRSSSV amco MAE SV W13 813' nipple am W axx 3.813 Vam Tap pin 13325.4 6648.1 63.03 %Nipple Camcu 4-1/7 x 3.813" X landing nipple 3.813 1 ,343A 6,6552 63.22 Baker it Bader T'x45' non sealing Kong stub overshot (610'Swallowl 4670 Overshot g Dexrlptbn ably Me... to pp Tap lflKal set Di'. set D¢pn mpl (... vn limp 6rMe TopCmneatbn TUBING ORIGINAL 412 3.96 13,339.0 13,421.3 8690.8 12.60 L-80 IBTM Completion Details TOPm'p Topmm nominal Top Yong pKp fl 12m Des cam ID in) 13.3651 6.666.0 6349 PACKER BAKERS -3 PACKER 13A09.1 6,6854 64.04 IHES XN NIPPLE 3]25 13420.0 Q690.2 I 64.1) WLEG WIRELINE GUIDE 3.875 GWhMNNq:,a,xTe Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ND) Top Incl Top(..) (land f) San Com qun Deb ID pn) P.w., ITutiyE ta.z�6 13,359.0 6,663.3 63.41 I EVO I Dias PLU 45EVO TREIV PLUG (UAL =16) 3Ifl12019 0.000 Nlandrel inserts st mi N Top IXKd TOPIrvd IXKB) Make Model OD(inl Sery valve This Iatcn Type portaim Nn) TRO Rvn IPsll Run Date Cam t 13,26].8 6,621.9 Camm KBG-2 1 GAS LIFT DMY NK 326121119 %Nppe: 19.33•v.d Notes: General 8 Safety End Date Annotation 6/22/2010 i i NOTE: View Schematic w) Alaska Schematic9.0 12/112015 NOTE:Waiver T%IA ommaneraten ]/15201] N TE: G(M A KS HIGH SEALABILLINFRIEUDENBURG PACKING FOR GASPER PACKING MANDREL dNe.PoapryDver taau4 PACKER.19,365,13 NIPPLE', 13,409.1 vnE6 x®o INTERRED WTE:34.4,IsM.1 1111 tall OPEN Ni 14,0710-10.919 ear • Operations Summary (with Timelog Depths) CD1-14 Rig: DOYON 142 Job: RECOMPLETION Time Log start Mme End Time Dur (hp Phase Op Code Activit' Code Time P -T -X Operation SMO Depth (flKB) End Depth (fiKB) 3/10/2019 3/10/2019 7.00 MIRU MOVE RURD P Remove beaver slide. Hang and 0.0 0.0 12:00 19:00 secure skate track. Blow down steam and water systems. Disconnect interconnects. Sim-ops/Move camp to CD -4 ice pad, 3/10/2019 3/10/2019 3.00 MIRU MOVE MOB P Pull support mods apart and stage on 0.0 0.0 19:00 22:00 pad. 3/10/2019 3111/2019 2.00 MIRU MOVE MOB P Move motor, pump and pit modules 0.0 0.0 22:00 00:00 towards CD1 3/11/2019 3/11/2019 1.00 MIRU MOVE KURD P Move scaffold on adjacent well to 0.0 0.0 00:00 01:00 raise stomper. 3/11/2019 3/11/2019 0.50 MIRU MOVE MOB P Pull subdstructure off of CD3 -123. 0.0 0.0 01:00 01:30 3/11/2019 3/11/2019 2.00 MIRU MOVE MOB P Stage sub and pipeshed on ice pad 0.0 0.0 01:30 03:30 and fuel trucks. 3/11/2019 3/11/2019 6.00 MIRU MOVE MOB P Move sub and pipeshed from CD3 to 0.0 0.0 03:30 09:30 CD1 3111/2019 3/11/2019 2.50 MIRU MOVE MOB P Line up sub on CD1-14. Retract 0.0 0.0 09:30 12:00 stompers and cellar wind walls. 3/11/2019 3/11/2019 2.00 MIRU MOVE MOB P Lay herculite and dg mats around well 0.0 0.0 12:00 14:00 CD1-14. 3/11/2019 3/11/2019 2.00 MIRU MOVE MOB P Spot substructure over CDi-14. Set 0.0 0.0 14:00 16:00 stompers. Remove load hitch. Skid rig Ito drilling position. 3/11/2019 3/11/2019 0.50 MIRU MOVE MOB P DSM move flow line pedestals for 0.0 0.0 16:00 16:30 stomper clearance 3/11/2019 3/11/2019 1.50 MIRU MOVE MOB P Set stompers. Remove load hitch. 0.0 0.0 16:30 18:00 Skid dg to drilling position. 3/11/2019 3/11/2019 3.00 MIRU MOVE MOB P Lay mats and herculite. Spot pit room 0.0 0-- 18:00 21:00 and pump room. 3/11/2019 3/11/2019 2.50 MIRU MOVE MOB P Lay mats and herculite. Spot motor 0.0 0.0 21:00 23:30 room and rock washer. 3/11/2019 3/12/2019 0.50 MIRU MOVE MOB P Spot pipeshed. 0.0 0.0 23:30 00:00 3/12/2019 3112/2019 0.50 MIRU MOVE MOB P Continue sptotting pipeshed. Set in 0.0 00:00 00:30 handl-berm around the rig 3/1212019 3/12/2019 4.75 MIRU MOVE MOB P Hook up inter -connect in sub, 00:30 05:15 pils,pump room. Install skate, beaver slide. Complete rig check list. Rig Accepted @05:15 Hrs. 3/12/2019 3112/2019 5.00 MIRU WELCTL SEQP P R/U hard lines in cellar T/flow flow 05:15 10:15 back tank. Pressure test line to 3500 psi. 3/12/2019 3/12/2019 0.75 MIRU WELCTL MPSP P FMC Rep. pulled BPV 0 psi. on the IA 10:15 11:00 I 0 psi. on the tubing 3/12/2019 3/12/2019 1.00 MIRU WELCTL RURD P Blow down lines, rig up tioga to aux. 11:00 12:00 choke house 3/1212019 3/12/2019 2.50 MIRU WELCTL CIRC P Rev. Circ 8.6ppg. seawater down the 12:00 14:30 IA returns up the tubing to the flow back tank. tbpm 65psi., 1.5 bpm 310psi. 70bbl. pumped until seawater back to the flow tank 3/12/2019 3/12/2019 2.75 MIRU WELCTL CIRC P Pumped down the tubing 8.6ppg. 14:30 17:15 seawater take returns through the IA to the flowback tank ICP 1.5bpm 45psi. FCP=380psi. @ 1.5bpm. total returns to tank =154 Page 115 Report Printed: 4/5/2019 Operations Summary (with Timelog Depths) CD1-14 Rig: DOYON 142 Job: RECOMPLETION Time Log J Sten Depth StartTime End Time Dur(hr) Phase Op Cotle Ad ity Coce Time P-T-X Operation (ftKa) End Depth (flKe) 3/12/2019 3/12/2019 1.00 MIRU WELCTL OWFF P Slut in well, pressure gauge had 90 17:15 18:15 psi. open well bled presure down to 0. shut in well and monitor for 30 min. well stayed static. 3/1212019 3/12/2019 0.50 MIRU WELCTL OWFF P Monitor well to open atmoshere No 18:15 18:45 Flow 3/12/2019 3/12/2019 2.00 MIRU WELCTL MPSP P FMC Rep. bled hanger void, set HP 18:45 20:45 BPV Test to 1000 psi.110. Bikow down and dg down circ. lines 3/1212019 3/12/2019 1.25 MIRU WHDBOP NUND P Nipple down tree,Disconnect and 20:45 22:00 secure SSSV control line. install blanking pluig with FMC rep. 3/12/2019 3/12/2019 1.00 MIRU WHDBOP NUND P Nipple up 2'-13-518 x 13 5/8 spacer 22:00 23:00 spool to wellhead spool. 3/1212019 3/13/2019 1.00 MIRU WHDBOP NUND P Nipple up 13 5/8 BOP 23:00 00:00 3/13/2019 3/13/2019 6.00 MIRU WHDBOP NUND P N/U BOPE, Install choke line, Kill line, 00:00 06:00 Riser, Prep Floor to test ROPE. 3/13/2019 3/13/2019 9.00 MIRU WHDBOP BOPE P Test BOPE 250/3500 psi. 5 min low 5 06:00 15:00 min hig, all tests was done with 4" and 4 1/2 " test joint. all choke vavles and floor were test 25013500, manual and super choke was tested @ 200 psi. AOGCC. Guy Cook waived to witness test. 3/13/2019 3113/2019 1.00 MIRU WHDBOP BOPE P Blow down test equipment. 15:00 16:00 3/13/2019 3/13/2019 3.50 MIRU WHDBOP RGRP T Rig up and test HP mud line. change 16:00 19:30 out O-ring on hammer connection in pits interconnect. 3/13/2019 3113/2019 3.50 MIRU WHDBOP RGRP T Thaw out cellar choke line, remove 19:30 23:00 choke line from BOPE. thaw out and make choke line back up to BOPE and retest. 250/3500 psi. 3/13/2019 3/13/2019 0.50 COMPZN RPCOMP RURD P Rig up casing equipment 23:00 23:30 3/13/2019 3113/2019 0.25 COMPZN RPCOMP MPSP P Pull blanking plug and BPV. Monitor 23:30 23:45 well for 10 min's. Static. 3/13/2019 3/14/2019 0.25 COMPZN RPCOMP THGR P PJSM-Make up landing joint and X-O 23:45 00:00 to top drive. BOLDS. Unseat hanger with 105K PU. Pull to 185K to free pipe. 168K free travel PU. wt. Pull hanger to rig floor. 3/14/2019 3/14/2019 2.50 COMPZN RPCOMP THGR P Continue Pulling to 185K to free pipe. 00:00 02:30 168K free travel PU. wt. Pull hanger to dg floor. 3/14/2019 3/14/2019 2.00 COMPZN RPCOMP RURD P Terminate Chem. injection line & 02:30 04:30 SSSV control line. Lay down tubing hanger. Rig up control line spooler. 3/14/2019 3/14/2019 3.75 COMPZN RPCOMP CIRC P Circ. @ 252 gpm, 7% flow 747psi. 04:30 08:15 Max gas 5120 units. 12,731 total strokes pumped until gas diminished. 3/14/2019 3/14/2019 0.50 COMPZN RPCOMP OWFF P monitor well, NO FLOW 08:15 08:45 3114/2019 3/14/2019 4.25 COMPZN RPCOMP PULL P POOH on trip tank w/ 4.5" 12.6# L-80 13,141.0 10,958.0 08:45 13:00 TXP tubing, from 13,141'to 10,958' MD ( 55 jnt. of TXP 56 full cannon clamps, 3 s.s. bands and 112 pins 3/14/2019 3/14/2019 0.75 COMPZN RPCOMP RURD P Rig down and Gear from floor SLB 10,958.0 13:00 13:45 1 control line spooler. Lay down SSSV. 3/14/2019 3114/2019 9.75 COMPZN RPCOMP PULL P Continue POOH on trip tank w/ 4.5" 10,958.0 0.0 13:45 23:30 12.6# L-80 hydril 563 tubing, from10,958' - Surface MD Page 215 ReportPrinted: 41512019 Operations Summary (with Timelog Depths) CD1-14 Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depih Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (M(8) End Depth(MB) 3/14/2019 3/15/2019 0.50 COMPZN RPCOMP RURD P Rig down casing equipment. 0.0 23:30 00:00 3/15/2019 3/15/2019 6.50 COMPZN RPCOMP P Load pipe shed with. Of 4" drill pipe 18 00:00 06:30 jnt. HWDP and process. 3/15/2019 3/15/2019 1.75 COMPZN RPCOMP BHAH P Make up clean out BHA #1 with Baker 06:30 08:15 Rep. 3/15/2019 3/15/2019 1.25 COMPZN RPCOMP TRIP P RIH with 4" HWDP T/637' 0.0 637.0 08:15 09:30 3/15/2019 3/15/2019 3.50 COMPZN RPCOMP TRIP P RIH with 4" DP F/637' T/3,897' MD 637.0 3,897.0 09:30 13:00 3/15/2019 3/15/2019 8.25 COMPZN RPCOMP CIRC P Circ. @ 3,897' 6bpm 640 psi. 7% F/O 3,897.0 13:00 21:15 Simops ; Load/Strap 302 jnt. of 4" DP in pipe shed 3/15/2019 3/16/2019 2.75 COMPZN RPCOMP TRIP P Continue RIH F/ 3,897' T/6,344' MD 3,897.0 6,344.0 21:15 00:00 PIU 118k SIO 90k 3/16/2019 3/16/2019 7.75 COMPZN RPCOMP PULD P Continue RIH with clean out BHA on 6,344.0 13,136.0 00:00 07:45 4" drill pipe from pipe shed. F/6,344' - /6,344'- T/1 3,136 T/13,136 3/16/2019 3/16/2019 0.75 COMPZN RPCOMP CIRC P Establish parameters and clean out 13,136.0 13,330.0 07:45 08:30 casing with casing scraper. 13,136' - 13,330' 40rpm, 10k tq 5bpm, 916 psi. pick up = 194k slack off= 110k Rol. _ 144k 3/16/2019 3/16/2019 0.50 COMPZN RPCOMP WASH P Tagged up on tubing stub @ 13,344' . 13,330.0 13,344.0 08:30 09:00 washed over stub and dress off with 7' of the swallow. Rotate 40-60 rpm. 10- 14kTQ. 5bpm 920 psi. 3/16/2019 3/16/2019 3.00 COMPZN RPCOMP CIRC P Pick up above stub and circ. at 13,344.0 13,335.0 09:00 12:00 13,335. pump 6bpm 1229 psi. laod pipeshed wiih 4.5 " tubing and Process for completion 3/16/2019 3/16/2019 0.50 COMPZN RPCOMP OWFF P Monitor well, (no flow) blow down 13,335.0 12:00 12:30 equipment. 3/16/2019 3/17/2019 11.50 COMPZN RPCOMP PULD P POOH UD 4" ddllpipe F/13,335'to 13,335.0 3,063.0 12:30 00:00 3,063 3/17/2019 3/17/2019 2.00 COMPZN RPCOMP PULD P UD 4" Drill pipe from 3,064 - to 637' 3,063.0 00:00 02:00 3/17/2019 3/17/2019 1.50 COMPZN RPCOMP BHAH P UD BHA: HWD, Baker scraper/ dress 02:00 03:30 off mill. dean magnets and boot baskets (boot baskets brought back oily mud) 3/17/2019 3/17/2019 0.75 COMPZN RPCOMP OTHR P Pull wear bushing and Orient tubing in 03:30 04:15 pipe shed 3/17/2019 3/17/2019 1.00 COMPZN RPCOMP RURD P Change out handling equipment, 04:15 05:15 stage completion jewelry on the floor rig up power tongs. 3/17/2019 3/17/2019 8.75 COMPZN RPCOMP RCST P Pick out overshot and RIH with hydril 0.0 05:15 14:00 563, torqued att dope connections 3,800 Rubs torqued dopeless connections to 4,600 f7lbs PIU = 100k S/O = 80k 3/17/2019 3/17/2019 0.50 COMPZN RPCOMP RURD P Mobilize SLB control line spooler to 7,105.0 14:00 14:30 the rig floor. 3/17/2019 3/17/2019 0.50 COMPZN RPCOMP SVRG P Grease and inspected, drawworks, lay 7,105.0 14:30 15:00 down machine and Top Drive 3/17/2019 3/17/2019 3.50 COMPZN RPCOMP RCST P Continue running 4.5" 12.6# L-80 7,105.0 11,008.0 15:00 18:30 hyddl 563 Tbg. from 7,105' -to 11,008' P/U = 142K SIO = 87k 3/17/2019 3/17/2019 3.50 COMPZN RPCOMP RURD P SLB tie-in sssv, hang sheave control 11,008.0 18:30 22:00 line, mobilize cannon clamps/SLB handling tools. Test sssv to 7500psi. 15min. Page 3/5 Report Printed: 415/2019 Operations Summary (with Timelog Depths) CD1-14 Rig: DOYON 142 Job: RECOMPLETION Time Log Start -rime End Time Dur (hr) Phase Op Code nctiviry Code Time P -T -X Operation Star) Depth (ttK8) End Depth(X(B) 3/17/2019 3/18/2019 2.00 COMPZN RPCOMP RCST P Continue running 4.5" 12.6# L-80 11,008.0 12,928.0 22:00 00:00 hydril 563 Tbg. from 11,008'- to 12,928 P/U = 155K S/O = 95k cannon clamps every connection 3/18/2019 3/18/2019 1.00 COMPZN RPCOMP RCST P Continue running 4.5" 12.6# L-80 12,928.0 13,347.0 00:00 01:00 hytlril 563 Tbg. from12,928' - 13,347 P/U -= 162K S/O = 93k cannon clamps every connection 3/18/2019 3/18/2019 0.50 COMPZN RPCOMP RCST P Tagged up @ 13,347' set down 5k 13,347.0 13,351.0 01:00 01:30 picked up off stump. set back down Sk and observe shear. slacked off and set down on no go @ 13,351' set down 7k, picked up and set down to tag no go again to verify depth. 3/18/2019 3/18/2019 0.50 COMPZN RPCOMP HOSO P Lay down 3 jts. pickup two 5.82 pups 13,351.0 13,347.0 01:30 02:00 and make up to string pick back up jt. 330 and run in the hole. 3/18/2019 3/18/2019 1.50 COMPZN RPCOMP THGR P Make hanger and pup and landing 13,347.0 02:00 0330 joint. run chem line and sssv control line through hanger. PT fittings to 5000 psi. land hanger , run in lock down screws. 163k p/u, 94k S/O. observe drad to 91k while landing. indication of PB overshot engaging stump. 58 cannon clamp 3 bands install on string 3/18/2019 3/18/2019 5.00 COMPZN RPCOMP CRIH P Pump 255 bbl. of sea water, follow 03:30 08:30 with 40 bbl. of corrosion inhibited brine and chase 183bbt. of sea water to spot Cl pump @ 3bpm 590 to 800psi. 3/18/2019 3/18/2019 2.50 COMPZN RPCOMP THOR P Rig up and test hanger seals 250 low 08:30 11:00 5000 high for 10min. 3118/2019 3/18/2019 2.50 COMPZN R-PCO'MP PACK P Pressure up on the tubing & IA to 500 11:00 13:30 and shut in with TIW. rig up and lubricate in ball and rod. equalize pressure with tubing and lubricator. open TIW and allow ball and rod fall for 15 min. pressure up tubing to 4200psi. hold for 5 min. bleed pressure off to 2000 psi. pump down the IA and hold 3000psi. bleed down IA to 0 psi. pump down the IA to 2800psi., unable to shear, pump down the tubing pressure up to 3000 psi., pressure up the IA to 3000psi. bleed tubing to 0 psi. shear sov. Circ down the IA 5.4 bbl. @ 1.5bpm 275psi. 3/18/2019 3/18/2019 3.00 COMPZN RPCOMP SSSV P Pressure test sssv, 3000psi.-10 min 13:30 16:30 SLB pump up the control line to sssv to 5K Shut in tubing allow to bleed through isolation flapper valve, IA and Tubing equalized @ 2280psi. bled to 0. blow down equipment 3/18/2019 3/18/2019 1.00 COMPZN WHDBOP MPSP P FMC Install BPV. Test to 1000 psi. 16:30 17:30 hold for 10min 3/18/2019 3/18/2019 3.00 COMPZN WHDBOP NUND P Bleed off accumulater presser, pull 17:30 2030 mouse hole. N/D BOPE. 3/18/2019 3/19/2019 3.50 COMPZN WHDBOP NUND P FMC/SLB make sssv & chem line 20:30 0000 penetration through wellhead and secure. 3/19/2019 3/19/2019 2.00 COMPZN WHDBOP WWSP P Set and Orient tree. 00:00 0200 3/19/2019 3/19/2019 1.50 COMPZN WHDBOP WWSP P Test tree 250/5000 psi. hold for 5min 02:00 03:30 Page 415 Report Printed: 4/5/2019 -- Operations p Summary (with Timelog Depths) r rt` CD1-14 Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Code Acvviry Code Time P -T -X Operation Start Depth (ftKB) End Depth dtKB) 3/19/2019 3/19/2019 0.50 COMPZN WHDBOP FRZP P Rig up to freeze protect 03:30 0400 3/19/2019 3/19/2019 2.50 COMPZN WHDBOP FRZP P Pump 96bbl. of diesel freeze protect 04:00 06:30 down the IA. Taking returns up the tubing. Final rate and pressure 1.5 bpm @ 250 psi. 3/19/2019 3/19/2019 2.50 COMPZN WHDBOP FRZP P Allow freeze protect to U-tube at 06:30 09:00 surface until IA and tubing are equal. 3/19/2019 3/19/2019 1.00 COMPZN WHDBOP MPSP P Install BPV , install tree cap, installl 09:00 1000 blanks on valves on tree and secure. 3/19/2019 3/19/2019 2.00 DEMOB MOVE RURD P Secure cellar, Rig down tool slide. 10:00 1200 skate rails and work on the interconnects Rig Released @ 12:00 hrs 3/19/19 Page 515 Report Printed: 4/5/2019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Ward Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD1-14 Permit to Drill Number: 201-038 Sundry Number: 318-553 Dear Mr. Ward: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, a o g c c. a l a s k a. g o v 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, Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2019. SCANNED F=3 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate 0 Repair Well '' Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑Q Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli sAlaska Inc. Exploratory ❑ Development ❑ Stratigraphic El Service • 201-038 ' 3. Address:❑� 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20371-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this po N/A CRU CD1-14 Will planned perforations require a spacing exception? Yes ElNo 9. Property Designation (Lease Number):A_bj_g5 10. Field/Pool(s): ADL 0025559 Colville River Field / Alpine Oil Pool ' 11. a_ lZ' It PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft) Effective Depth MD: Effective Depth ND MPSP (psi): Plugs (MD): Junk (MD): 18,939' 6,814' 18,939' 6814" 3348 Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 115' 115' Surface 3,550' 9-5/8" 3,587' 2366 Intermediate 14,039' 7" 14,073' 6855' Production Open Hole 4866' 6-1/8" 18,939' 6,814' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4.500" L-80 13,420' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): SSSV - BP6i HYD Nipple WRDP MD= 2293 ND= 1830 PACKER - BAKER 4-1/2" PREMIER PACKER MD= 13141 ND= 6563 PACKER - BAKER S-3 PACKER MD= 13365 ND= 6666 12. Attachments: Proposal Summar Wellbore schematic P1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 2 ' 14. Estimated Date for 3 g 15. Well Status after proposed work: CL r 16 Commencing Operations: .31z316q OIL ❑/ WINJ Elrt, i'; WDSPL El Suspended El16. GAS- y� WAG' GSTOR ElSPLUG El 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: DustyWard Contact Name: Dusty Ward Authorized Title: Sr. Wells Engineer Contact Email: Dusty.Ward@conocophillips.com Contact Phone: ;907) 265-6531 Authorized Signature: Llez- Date: 1 ' ' as COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test LK Mechanical Integrity Test Location Clearance ❑ Other: B o lam i-r,5y- 7'D 3✓TD O S t Z✓��5'% �'yyl7✓{9Y re- It / ��f pp f1 Var7la17Cc75- yrat'rtpd 7'o aglow ihr �uc�o�sh halt 7:�f�1'r�� Bao �� a b o ✓C /-'p7P ffi9C zs. i z(6 Post Initial Injection MIT Req'- Yes �No ❑ a o Spacing Exception Required% Yes No Subsequent Form Required: /D D%f' APPROVED BY .Z.. Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Corm 10-403 revised 4/2017 Approved a l- I-qqyy�S V fP f 12 t from the date of approval. Attachments' Du licate PP ppl- CC I RBDMS�Ft8 0 ►Ie /�� .y, rV ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 6 Dec, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 ! Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. (CPAI) hereby applies for Sundry Approval to workover Alpine Black Start Gas Storage Injector CDI-l4 (PTD# 201-038). CDI-14 was drilled and completed in May of 2001 as Alpine's Black Start gas storage well. When fuel gas is unavailable due to plant outage, CDI-14's injected gas is produced to provide fuel for the electrical generation system at Alpine. This system is critical for Alpine camp operations, process safety in the production facility (heat, lights, instrument air, etc.), and is required to restart the production facility after any planned or unplanned shut down. In August of 2015 CDI-14's inner annulus (IA) pressure was bled and increased to near pre -bleed pressure, indicating tubing by IA (TxIA) communication. In 2017, a workover was performed to remediate the TxIA communication, which was thought to be due to seals in the tubing hanger. A Premier Production packer was stacked with a variance at 13141' RKB. The well passed on -rig tubing pressure test (PT) to 4000 PSIG and annulus PT to 2500 psi on 4/14/2017. An SOV was sheared, mud was circulated out, and a OMIT on tubing and IA was performed to 3,500 psig for 30 minutes on -rig. Post the RWO, a 3,000 MIT -IA passed on 6/10/2017, however, rapid increase in IA pressure was again noticed on 6/15/2017, indicating T x IA communication. Various components of the completion are suspect as being the cause, but a flow -cut GLM from circulating out the mud at the last workover is the lead issue. A patch was placed across the GLM to attempt to stop the T x IA communication. The SSSV has also had various issues with getting valves to seat in it since the last workover. The well is planned to be worked over to repair the well with gas tight tubular connections to surface, a new GLM, and a new SSSV. The well will have a plug placed in the XN-nipple profile at —13409' RKB as a barrier to the formation. The tubing and stacked packer will be pulled down to the overshot above the current production packer. A cleanout run will be made to confirm access to the tubing stub from the 2017 workover. Then the well will be recompleted with a non - sealing overshot and a new stacked packer. The new stacked packer will be set at approximately 13250' RKB, which is about 400' below calculated TOC and 800' MD above open hole interval. If KWF is required, it should be a brine instead of a mud this time, and the procedure will be sensitive to any circulation that could potentially wash out the GLM. The SSSV will also be replaced. This Sundry requests a variance from 20 AAC 25.412 to allow the stacked packer to be set approximately 800' MD above the open hole interval. If you have any questions or require any further information, please contact me at 265-6531. Sincerely, Dusty Ward Senior Wells Engineer CPAI Drilling and Wells CD1-14 RWO Procedure Alpine Injector PTD #201-038 Pre -Rig Work 1. Remove tubing patch. 2. Get additional SBHP. 3. Set plug in tubing tale XN nipple at 13409' RKB to isolate RWO from formation. 4. Cut stacked Premier Packer at -13150' RKB. (Allows straight pull to release packer slips and elements.) 5. Confirm deepest GLM is open. 6. Install BPV. Rig Work MIRU 1. MIRU Nordic 1. 2. Record shut-in pressures on the T & IA. Plug and packer should provide competent barrier. If there is pressure, bleed off IA and/or tubing pressure and pull BPV. Complete 30 -minute NFT. Verify well is dead. a. Primary barrier: Plug, packer and competent casing. KWF will be available as backup primary. b. Secondary barrier: Packoffs and Tree OR BOP. (BPV in place and confirmed in direction of flow while swapping tree to BOP and vice versa.) 3. Set BPV if pulled to bleed off pressure, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. a. MPSP of 3348 PSIG calculated from SBHP of 4016 at 13409' RKB (6685' TVD) on 10/30/2018. Retrieve Tubing Section 4. Pull BPV, MU landing joint and BOLDS. S. Pull 4-1/2" tubing with Premier packer and overshot attached (down to 13340' RKB), standing back tubulars to use as workstring. 6. MU cleanout BHA. RIH with cleanout BHA on workstring to top of old tubing stub at —13340' RKB. Install in 41/2" and 3-3V Gas Tight Tubing 7. MU 4-1/2" completion with non -sealing overshot, nipples, packer, GLMs, SSSV, and chemical injection valve. Pressure test control line and chemical injection line. RIH and confirm overshot has engaged tubing stub. 8. Space out, land tubing hanger and install packoffs. 9. Drop ball and rod and set packer top @ approximately 13250' RKB (6614' TVD) w/ completion. a. TOC estimated at 12846' RKB (6422' TVD). b. Packer would be approximately 800' MD above open hole section. 10. Pressure test tubing to 4200 psi for 5 minutes. 11. Pressure test inner annulus to 3000 psi for 30 minutes on chart. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV with pressure differential. 13. Install BPV. 14. ND BOPE. NU tree. 15. Freeze protect well. 16. RDMO. Page 1 of 1 CD1-14 Proposed RWO Completion 6.15" Open Hole @ 18939' RKB PROPOSED COMPLETION 4-1/2" 12.6# HYD 563 4-1/2" X landing nipple at -2180' RKB (3.812" min ID) 4-1/2" Chem Injection Nipple @ -2290' RKB 4-1/2" SSSV @ -2297' RKB 4-1/2" Carrico gas lift mandrels @ TBD Baker 4-1/2" Premier Packer xxxx' RKB (3.880" to) 4-1/2" 12.6# HYD 563 4-1/2" X landing nipple at xxxx' RKB (3.812" min ID) 4-1/2" Non -Sealing Overshot @ -13110' RKB REMAINING COMPLETION LEFT IN HOLE Baker 4-1/2" 8-3 Packer @ 13365' RKB (3.875" ID) HES XN nipple @ 13409' RKB (3.750" ID) Baker Wireline Entry Guide @ 13420' RKB /r'\ WNS INJ CD1-14 ConocoPhillips ff Well We""n;bvid Max Angle&MD TO & TO Alaska. T. W APIibu FiNtl Name WeI1Eore SMus Mf) I (flNBI 50103203] 100 ALPINE INJ 95.01 16,181 99 18.939.0 Comment N251ppm1 Ooh Mnolatbn End Oale Na -0N lltl Rlg Relmx Ga SSSV'. NR4DP Laa1Wtl. 4/16@01) 63.]0 5/1112001 c01.14.3r11.1911405. Last Tag eN®luln,reuc c MnaMion Depth 1 End Care Lst By Last Tag SUM 134208 2/14/2010 tamaj .420p rrod, HANGER: 319 Last Rev Reason AnnNMbnEntl Ooh Iay1MOE By Rev Reason: PULLEDWRDP, UPDATEDTAG, SETPATCH 3/182016 famaj Casing Strings Caning Cescrlpinn OD (in) IDllnl Top MEN Be,0epthheMb Sx Gerin N01._ Mor ll._ G. Top Th. CONDUCTOR 16 15082 3].0 115.0 1150 8258 H40 WELDED Cmlrp Deec,igion per Bn) ID 9n1 Top(nK91 SDepth 11181 Sat DapM I.3880 NDF.. WOLen11... u-21 TopTh- SURFACE 9518 0.921 36.0ed 3,586.5 2 6000 L-80 BTC -MOD Casing Rx,lpolon ODAnI to (InTop lnNBl Sar Oen. (M(Bl SEd DepMl (]VDI... WJten ll... Grate Top TMeN INTERMEDIATE ] 51M 34.3 14,073.1 6855.1 26.00 L-80 BTCM Caning Oex,ip"pur OD (.a, IDllnl Tap PIKE) 3e1 unpin pri SN Chath Bala. Wir ll... Grade Top Tin C OPEN HOLE 81/0 16,0]3.0 189390 8,8137 Tubing Strings ruan9 Da6CrlpEan sm,q Ma... lDlinl iop (noel iN OaWbIn.. 9e10.pM (1vq 1Wr 11Nx1 Grate Top wnnMion coxOucrOR: a]o-nso TUBINGRWp201] 41/2 3.908 319 13346] 6,657.8 12.6GL-60 Hydal SEE Completion Details Top Bvo) Top snot Nomlvl rop(nKel (noel 1°I Idem ons wm ID Bn) 319 31.9 0.12 HANGER FMC 4-i/2" Tubing Hanger Dnned to 3.90" 3.900 2,2925 1,829.0 6539 NIPPLE 45"X38]5"SP-6I HYD NIPPLE (12 Ed. B8D. Hydra 563 Box x 3.875 NIPPLE]E35 pjn) 2.290.9 18308 6543 NIPPLE 4.5"DCINII.CHEMICALINJECTIONASSEMBLY(12.M,L80, 3.068 Hynnl 553 Box x Pin) MPPLE:2M69 13,1412 6.563 661 9] PACKER Baker4-1I2'PremierPacker 9.880 13.2113 6.596.0 62.54 NIPPLE 4.5'x3813'DNELBWin9NiPPIe(128n,L-BD Hyonl%3BxP) 3.813 132]0.] 6.623.2 62.81 NIPPLE 4.5"3.812Xnipple (126a, L80, Hydbl 563 BOxxpin) 3.812 13,340.0 6,854.7 6318 POO, Bo' Baker Non -Seeing OVer5h01 4.]50 o erenm TubIn9 GF5CrIPdion 3ninp Ma...IGgn) Tap ldlk8l Ser Ceptlr IR. SN ppIn 1TV0) I... Wr p rob Grtle Top Cox-ehon II TUBING ORIGINPL 412 3.958 13,339.0 13.6213 8.890.8 1260 L-80 /BTM rilan.E:39.B3rade-j l Completion Detags TaPIND) Top and xomma Top lnMe) Nj'g ) Ihm N. CO. IDpn) 13.365.1 6,686.0 6309 PACKER BAKERS -3 PACKER 3.8]5 13A09.1 68854 8404 NIPPLE HES XN NIPPLE 3]25 GASLIFT:up]34 t3A200 fi6902 54.1] hi WIRELINE GUIDE 3.8]5 PATCw, mo5e0 Ogler In Hole (Wiralins retrievable plugs, valves, pumps, fish, etc.) TNI TnPma1 Top MB ryKBI 1°I Den Com Run ONe IDxn) 13.069.0 6,529.1 6143 PATCH WFO UPPER IMDEPAK PACKER AND SPACER PIPE 2R]I2018 2.240 PATCx:1aFB5O SETAT1305TIVIO13069'RKe OALI9MAXOD 372 13.085.0 6,536.7 61.53 PATCH WFD LOWER NADEPAK PACKER SET AT 13070' MD, 21192018 2.375 13CSTRKB. OAL6.6'. MAX003]2' Mandrel Inserts PACKER. 13,1412 6r HI N Tp,,,N, TOPtwo)valor IBKBI make Mo4N oGlinl Sery Tvw talcn TrPo Pan Brie 9n1 TRO Run /psi) Run Dace Go - 1 13,0734 6,5312 Camco KBG3 1 GABLIFT DMV BK 0900 OD ]/15201] EX Pecks ng NIPPLE, 13,2113 Notes' General & Safety End Dead Annotation &2212010 NOTE: yew Schematic wl Alaska Schematic9.0 12 /11 2 0 15 NOTE: Waiver ToACommunication ]I1&201] NOTE. GUM C/O -2 STACKS HIGH SF BILRV FREUDENBURG PACKING FOR GAS PER PACKING MANDREL NIPPLE: 133M.7 Pmr 8eY0wnML 13 Nn0 PP oo: 13,3850 NIPPLE: 13,409.1 WLEG', 13.aN.0 rI1 INTEAMEOIATE:M3140]31 J, ... OPENNOLE', 14.073.0.1UNhair 1-1ECEiVED STATE OF ALASKA • AMU OIL AND GAS CONSERVATION COMARION MAR 2 0 2018 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations ❑ Fracture Stimulate LJ Pull Tubing LJ 41:LI Pull LJ Performed: Suspend ❑ Perforate H Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _Tubing patch_ Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development ❑ Exploratory H 201-038 3.Address: P.O.Box 100360 Stratigraphic H Service ❑✓ 6.API Number: Anchorage AK 99510 50-103203710000 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0025559 CRU CD1-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 18939 feet Plugs measured feet true vertical 6814 feet Junk measured feet Effective Depth measured 14010 feet Packer measured 13141 feet true vertical 6855 feet true vertical 6563 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 115' 121' Surface 3550' 9-5/8" 3587' 2872' Intermediate 14039' 7" 14073' 6855' Production Liner Perforation depth Measured depth N/A feet SCOO True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) 4.5 L-80 13421'MD 6691'TVD Packers and SSSV(type,measured and true vertical depth) SSSV BP61 WRDP 2295'MD 1820'TVD Upper Patch Packer Weatherford Widepak 13069'MD 6529'TVD Lower Patch Packer Weatherford Widepak 13085'MD 6537'TVD Packer Baker Premier 13141'MD 6563'TVD Packer Baker S-3 13365'MD 6666'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20,AC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory H Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run H 16.Well Status after work: Oil H Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP H SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-062 Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity� riitSupervisor / ,,n J Contact Email: n2540(cr7conocophillips.com Authorized Signature: �: _l Date: 5 -/ -0- `' Contact Phone: 907-659-7126 Form 10-404 Revised 4/2017 RBDMSx' MAR 2 12018 Submit Original Only • • • Iry • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 17, 2018 Commissioner Hollis S. French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for a retrievable tubing patch set in ConocoPhillips Alaska, Inc. injector CRU CD1-14 (PTD 201-038). Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska,Inc. • • Date Event Summary Executive Previous diagnostics suggest the gas lift mandrel may be the source of the T to IA leakage in Summary the Alpine Blackstart well CRU CD1-14. A tubing patch was set across the gas lift mandrel at 13,073' RKB. After the patch was set, the IA pressure was bled and monitored to identify the effectiveness of the patch. 02/17/18 ATTEMPT TO SET 3.72"WFT WIDEPAK PACKER; LOST COMMUNICATION WITH TOOLS WHEN REACHING GLM @ 13,073' RKB. IN PROGRESS. 02/18/18 ATTEMPT TO SET 3.72"WFT WIDEPAK PACKER; UNABLE TO GET 3.81" SETTING TOOL THRU GLM @ 13,073' RKB. IN PROGRESS. 02/19/18 UNABLE TO WORK SETTING TOOL THRU GLM @ 13,059' RKB (ACX LOG DEPTH / NOT CORRECTED TO TBG TALLY). DECISION MADE TO SET 3.72"WIDEPAK PKR (#CPA450036) MID-ELEM @ 13,070.3' RMD (MID PUP JOINT BELOW GLM), 19.3' CCL TO MID ELEM, CCL STOP DEPTH- 13,051'. CORRELATED TO HAL ACX LOG 6-7 NOV 2017. SLICKLINE TO SET UPPER PATCH ASSY. 02/26/18 ATTEMPTED TO SET UPPER WEATHERFORD PATCH ASSEMBLY, ABORTED RUN @ 7200' RKB DUE TO NOT MAKING TARGET DEPTH IN TIME. IN PROGRESS 02/27/18 SET UPPER WEATHERFORD PACKER ASSEMBLY @ 13053' RKB, UNABLE TO LATCH LOWER PACKER TO CONFIRM FULLY STUNG IN. IN PROGRESS 03/01/18 (AC EVAL) : Bleed IA for BUR (Complete). Initial T/I/O = si?/2030/850. IA FL @ surface (charged). Well currently has a flow cross, rised & BOP's installed on tree w/danger tags, did not cycle SW's. SSSV has been removed & has 3375 psi on control line. Bled IA to 985 psi in 10 min (charged fluid), bled back 1.85 bbls. Starting T/I/O = si?/985/860. 15 min T/I/O = si?/1020/860. (+35). 30 min T/I/O= si?/1026/860. (+6). Final T/I/O = si?/1026/860. 03/17/18 IA pressure reading is 1088 psi, only 62 psi higher than IA reading on 3-1-2018. WNS INJ ID CD1-14 ConocoPhillips 1° Well Attributes Max Angle&MD TD Wellbore APl/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(flee) Alaska,Inc. 501032037100 ALPINE INJ 95.01 14,181.99 18,939.0 c'cro atW Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ".. SSSV:WRDP Last WO: 4/16/2017 43.70 5/11/2001 CD1-14,3/182018 11:22'05 AM Last Tag • Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By ........................................................__. Last Tag SLM 13,420.0 2/14/2018 famaj HANGER;31.9 7=ree.1111 Last Rev Reason IL'3a� Annotation End Date Last Mod By Rev Reason:PULLED WRDP,UPDATED TAG,SET PATCH 3/18/2018 famaj ME win Casing Strings • Casing Description OO(in) ID(in) Top(660) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 37.0 115.0 115.0 62.58 H-40 WELDED 1 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 36.8 3,586.5 2,366.0 40.00 L-80 BTC-MOD t Casing Description .OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.3 14,073.1 6,855.1 26.00 L-80 BTCM T� r'r im Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread OPEN HOLE 6 1/8 14,073.0 18,939.0 6,813.7 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;37.0-115.0 TUBING RWO 2017 41/2 3.908 31.9 13,346.7 6,657.8 12.60 L-80 Hydril 563 Completion Details Top(TVD) Top Incl Nominal Top(ftKB) (ftKB) r) Item Des Com ID(in) 31.9 31.9 0.12 HANGER FMC 4-1/2"Tubing Hanger Drifted to 3.90" 3.900 2,292.5 1,829.0 65.39 NIPPLE 4.5"X 3.875"BP-6i HYD NIPPLE(12.64,L-80,Hydril 563 Box x 3.875 ill NIPPLE;2,292.5 Pin) 2,296.9 1,830.8 65.43 NIPPLE 4.5"DCIN II,CHEMICAL INJECTION ASSEMBLY(12.6#,L-80, 3.868 Hydril 563 Box x Pin) NIPPLE;2,296.9 13,141.2 6,563.4 61.97 PACKER Baker4-1/2"Premier Packer 3.880 13,211.3 6,596.0 62.54 NIPPLE 4.5"x 3.813"DB6E Landing Nipple(12.6#,L-80,Hydril 563 BXP) 3.813 13,270.7 6,623.2 62.81 NIPPLE 4.5"3.812 X nipple(12.6#,L-80,Hydril 563 Box x Pin) 3.812 13,340.0 6,654.7 63.18 Poor Boy Baker Non-Sealing Overshot 4.750 Overshot Tubing Description String Ma...ID(in) Top(660) Set Depth(ft..i Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING ORIGINAL Completion Details 41/2 3.958 13,339.0 13,421.3 6,690.8 12.60 L-80 IBTM SURFACE;38.8-3,586.5-+ . Top(ND) Top Incl Nominal Top(ftKB) (ftKB) (°) cent Des Corn ID(in) 13,365.1 6,666.0 63.49 PACKER BAKER S-3 PACKER 3.875 13,409.1 6,685.4 64.04 NIPPLE HES XN NIPPLE 3.725 GAS LIFT;13,073.4 13,420.0 6,690.2 64.17 WLEG WIRELINE GUIDE 3.875 PATCH;13,069.0 e■ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) i.'I Top(ND) Top not Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) PATCH;13,085.0 13,069.0 6,529.1 61.43 PATCH WFD UPPER WIDEPAK PACKER AND SPACER PIPE 2/27/2018 2240 SET AT 13053'MD,13069'RKB.OAL 19'MAX OD i 3.72" 13,085.0 6,536.7 61.53 PATCH WFD LOWER WIDEPAK PACKER SET AT 13070'MD, 2/19/2018 2.375 13085'RKB.OAL 6.4'.MAX OD 3.72" Mandrel Inserts PACKER;13,141.2 An ali N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere, Type Type (in) (psi) Run Date Com 1 13,073.4 6,531.2 Camco KBG-2 1 GAS LIFT DMY BK 0.000 0.0 7/15/2017 EX Packi ng NIPPLE;13,211.3 Notes:General&Safety End Date Annotation 6/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 12/11/2015 NOTE:Waiver TxlA Communication 7/15/2017 NOTE:GLM C/O-2 STACKS HIGH SEALABILITY FREUDENBURG PACKING FOR GAS PER PACKING MANDREL NIPPLE;13,270.7 Poor Boy Overshot,13,340.0 PACKER;13,365.0 NIPPLE;13,409.1 WLEG;13,420.0 INTERMEDIATE;34.3-14,073.1 OPEN HOLE;14,073.0-18,939.0 "` THE STATE 01ALASKA GOVERNOR BILL WALKER Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CDI-14 Permit to Drill Number: 201-038 Sundry Number: 318-062 Dear Ms. Kautz: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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. DATED this 1 day of February, 2018. Sincerely, Hollis S. French Chair REDMS 1 '- FD C 6 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AA(-. 2F 2Rn RECEIVED FEB 14 20618 5 24(AOGCC 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: _Tubing Patch—P]. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑� 201-038 ' 3. Address: 6. API Number: P.O. Box 100630 Anchorage, Alaska 99510 50-103203710000 7. If perforating: N/A ✓ 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CRU CD1-14 - Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025559 Colville River Field/Alpine 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): 18939' 6814' 14010' 6855 1 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 115' 115' Surface 3550' 9-5/8" 3587' 2366' Intermediate 14039' 7" 14073' 6855' Production Liner Perforation Depth ME(ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4-1/2' L-80 13421' Packers and SSSV Type: SP61 WRDP; Packers and SSSV MD (ft) and TVD (ft): 2295' MD and 1830' TVD; Baker Premier Packer; . 13141' MD and 6563' TVD; Baker S-3 Packer 13365' MD and 6666' TVD 12. Attachments: Proposal Summary E Wellbore schematic L� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/15/2018 OIL ❑ 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: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: n2549 Conoco hllll S.Corn �Contact Phone: 907-659-7126 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �. Plug Integrity F-1SOPTest F] Mechanical Integrity Test u/ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes'd No ❑ RBDMS 6 2018 l Spacing Exception Required? Yes ❑ No Subsequent Form Required: !b — A 0 /t APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2-16 I�V �,� 0-4 NGINCAA Form 1 10-403 Revised 4/2017 Approved application i v li r t date of approval. ryT V'�G 2/l /n � l8 Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 11, 2018 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7' Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CRU CD1-14 (PTD 201-038) to set a retrievable tubing patch. Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, / Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. CRU CD1-14 DESCRIPTION SUMMARY OF PROPOSAL Tubing Patch for CRU CD1-14 CRU CD1-14 (PTD 201-038) is an injector that was reported to the AOGCC in June 2017 for suspect IA pressurization after a rig workover that was performed to eliminate previous tubing by IA communication. Subsequent diagnostics and research suggest the leak point could be the GLM at 13,073' RKB. ConocoPhillips Alaska, Inc. (CPAI) intends to set a tubing patch and then observe the well to confirm the effect of the patch. CPA] proposes the following repair plan: 1. Set a retrievable tubing patch across the GLM at 13,073'. Drawdown IA pressure to monitor IA pressure for build-up while the well is shut-in and identify effectiveness of patch. 3. Submit 10-404. 4. Perform State -Witnessed MITIA to AOGCC required pressure if well brought on stabilized injection. NSK Well Integrity Supervisor CPF3 & WNS WNS INJ CD1.14 ConocVP"11i'lips Well; AtmWtes Max Angle &.MD TD Ala$Kghlitc. WaRaweMWWI FInW NMe Wellbore 3lMus 501IX5203)100 PLPINf INJ 730195 MDIIIN1 95.01 14,181.99 MBIm Itt8.9 18,939.0 Camas. iamesprd MIs 8b8V: WROP amMMbn Ena Bale kRGnJ Ups" : W16=7 dRIP ReIeaN DYe 43.70 5'1112001 coma. ]aprzpn cRDvu VerlkM tt exue Mroln,bn Deglb (M(B) and Bale Mnattllon LW Mb4 By EM OMe LeMTa9.SLM Rev Raeson: PULLED WRDP b SLIPSTOP, SET pplovan 7/202017 HAVGEP: N 9� EVO,GLVC/OpkHe Nctee),SETWRDPP as ng Zirlings Caaing mewlial" OD (1731 ID un, 'al(mal) Smcapp(ma.) Sal.RPm(rVD)... WIILen I1...GMe iap TnnM CONDUCTOR 16 15.082 370 116.0 115.0 62.58 H O WELDED call Onw"Iman 00 (in) ID 11.1 Tap IXKBI eel Dep[bfXlL81 eel DePln Ti Vis, WYLen 11.. GMe iaP Tart. SURFACE 9518 8.921 388 3,586.5 2,366.0 40.00 L80 BTC -MOD I CabI,M Beacnpllan 08 (1731 ID (1731 Tappies, pon-Pan'-j 5'n-Im. (PAI... VIYI.n (1... Grtle Tep T. as INTERMEDIATE ] 8.2]8 34.3 14.OTJ.1 6,855.1 26.00 L80 BTCM .-., Oe .,'an OD (lin m1101 TOP IhKB) 9N.'am mu ..-PnITVGI...YNLen 11... GMs TOP Thmp OPEN HOLE 6118 14.073.0 18,939.0 8813 ] Tubing Strings TYbIn9 DeatnPllan 5'1,1730 Ma.. IOpn) TOPInKB) Sal Oepla ln.. aM Opltt (TN)( N1IIbM) GMe ioP ConnMlen TUBINGRWO2017 412 3908 31.9 13,348) 8.657.8 1280 L80 Hydr11563 Completion Details xomIn) lD caxMlcioRlala nsa rbP (01(8) TOP I]VBl (31.9 raP 111012 Item Bee Lmm B. 31.9 3L8 0.12 HANGER FMC 4-12'Tubing Nangu Otlfletlb3.9D' 3.950 2,212.5 1,829.0 65.39 NIPPLE 4.YX3875" RPBi HttI NIPPLE (12BN, LBG Hyland 683 3875 Boxx Pin) 22 9 1,830.8 6543 NIPPLE 4.6.00IN II, CHEMICAL INJECTION ASSEMBLY (12.80, 3888 LW, HyddI 563 BOK x Pin) ."Pa 13,141.2 6,563.4 61.97 PACKER Baker 4 -VT plains, Packer 3880 PIBxG arov: u93Y 13,211.3 8598.0 6254 NIPPLE 4.5'x3.81W OBBE Landing NiWis(12.69, 1410, Hydrll 3813 603 Bxp) 13,270.) 6,823.2 62.81 NIPPLE 4.F 3.812 X nipple (12.60, 1410, Hydra 563 Bok x Pin) 3,812 ..an 21asD 13.340.0 6.854.7 83.18Pow Boy Baku Non -Sealing Descant4.750 NIPPLE. 1¢96s Overshot TUMIq 0.aa,- 817300 Ms... ID no, Tap InKB) an-amn-jon Deptn(TwII... vn (mm) GMe Top ConnMlen TUSINGORIGINAL 412 3.958 13,339.0 13,421.3 6.690.0 1260 L80 IBTM Completion Details xaminal ID Tap(ML91 Top(iV0)(n:0) '"ac'I Item Do Can I'm 13.385.1 6,666.0 6349 PACKER BAKER S3 PACXER 3.875 13,408.1 8.885.4 84.04 NIPPLE HES XN NIPPLE 3.T25 TJA .0 I 6, .2 64.17 WLEG WI ELINE GUIDE 3.075 MIRPADE; 373. }asses- Omer In Hole (Woeline retrievable plugs, valves, pumps, fish, etc.) rev lrvol Topmm Tap lXrcel Inrcel O Bee Can Run mu Is" o Bq 2,293.0 1,829.2 85.40 IDBING 4.5"SLIPSTOP(OAL=20.5 ]/IBM2017 0.000 STOP call 130734 2,295.0 1.890.0 BSA2 "Al BPM WRDP(5N; HAAS -50G. 3Akpl N0 -i" J/18201] 1.9'0 - FRUEDENBURG PACKING ON BTM. OAL�W Mandrel Inserts an as X rapinxe) TOp DVD) (he.) M.a. me4e1 I. aen wive Tyw LMen Type pal Mxe (ml rao thus (Pe8 Run Bae cam PaCKErtam O.l 1 1 ,0T3.4 31.2 Camco L K 0 UX111 l I Pack all Notes: General & Safety Eae I. Astacus, R2y2J10 NOTE: View schematic At Alaska 3cnematag.0 xals ¢m15 12,I 16 NOTE: Wairar TYA CommuskaYon 1 :GL C/O-2STACKS HIGH SILRY FREUDE BURG PACYANG FOR GAS PER PACKING MANDREL NIPFLE', 111. 1 sawasewsp allsin0 PACKER:13365.0 kklae :III.Id WLEG:I.Q,,a IMIERMFMxiE: )4}IrcOx].1 OPEN HOLE; I4A>)Otnaea0�'-- - Loepp. Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent: Thursday, February 15,2018 12:14 PM To: Loepp,Victoria T(DOA) Subject: 10-403 Form for CRU CD1-14(PTD 201-038) Attachments: CD1-14 Submitted 10-403.pdf Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, There is an ongoing tubing by IA communication troubleshooting in CRU CD1-14(PTD201-038).The attached 10-403 Form asks for an approval to set a retrievable tubing patch across the GLM.The Form was submitted on February 11th by mail from Kuparuk office. It might take some time before you receive it. Given the high activity level at Alpine during the Ice Road Season,there is an opportunity to perform the work in CD1-14 this coming Sunday 18th. I am kindly asking for your permission to proceed according to the proposed plan outlined in the Form before you receive the hardcopy. Please,contact if you have any questions at 263-4039. Regards, ILNUR Ilnur Mustafin Production Optimization Engineer ConocoPhillips Alaska SCANINEV Phone: 907-263-4039 ` f Email: ilnur.mustafin@conocophillips.com 1 ®3S, • 2.1SMC0 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 20, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED DATA LOGGED k n4/2o11, Anchorage, Alaska 99501 K BENDER DEC 222017 AOGCC RE: Leak Detect Log with ACX: CD 1-14 Run Date: 11/5/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20371-00 Leak Detect Log with ACX 1 Color Log 50-103-20371-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 eo ' �� Office: 907-275-2605I ,< IP f '� FRS_ANC@halliburton.com Date: Signed • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, October 16, 2017 1:50 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: CD1-14 (PTD 201-038,AIO 18C.006) high IA pressure Chris, Per our discussion earlier this morning,CPAI intends to delay the State-witnessed MITIA for Alpine gas injector(`Black start')CD1-14(PTD 201-038,AIO 18C.006) until after we have performed additional diagnostics. We will leave the well on gas injection to facilitate diagnostics,for no more than 28 days unless we seek further approval from you. During this time,we'll continue with our monitoring of the well trends and attempt to gather data through leak detect logging. At the conclusion of these diagnostic efforts,we'll report to you with our intended path forward. Please let me know if you have questions or disagree with this plan. Thanks, Travis SCANNED €- 1 / b From: NSK Well Integrity Supv CPF3 and WNS Sent: Friday, October 13, 2017 7:00 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CD1-14(PTD 201-038,AIO 18C.006) high IA pressure Chris, Alpine gas injector(`Black start') CD1-14(PTD 201-038,AIO 18C.006)was recently brought back on to gas injection. It's return to service following a rig workover and period of diagnostics had been delayed due to facility logistics and limitations. The IA is showing an increasing pressure trend—currently it shows^'1600 psi. CPAI had brought this well online with the intent to achieve stabilized injection and perform a State-witnessed MITIA on this upcoming Wednesday October 18, 2017. We still intend to perform this test,and will notify AOGCC Inspectors through the normal process. This well has recently demonstrated integrity of all packoffs(June 18,2017)and had a passing State-witnessed MITIA (June 10, 2017). Because of these circumstances,we propose leaving the well on injection until after the upcoming MITIA. At that point,we will update you as to the results and our proposed path forward for further troubleshooting. Please let me know if you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 Cletk c6 t- IA • • z&,030 Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday,July 19, 2017 11:50 AM "�'[ l ?'Z5(17 To: Regg, James B (DOA) I Cc: Wallace, Chris D (DOA); Senden, R. Tyler Subject: CD1-14 (PTD 201-038,A10 18C.006) Jim/Chris: I wanted to give a status update on our troubleshooting at CRU CD1-14 (PTD 201-038). Slickline recently completed a procedure to swap the dummy valve in the well's GLM. Because of residual workover fluids, this operation took several days but it looks as though it concluded with a proper set of a dummy valve—both an MIT-T and MIT-IA passed during the service work. The next step will be to bring the well online for an injection period to stabilize and fully ensure there is no remaining TxIA communication. We will notify you when we bring the well back online, as well as give a notification for the witnessed MITIA at that time. Please let me know if you have any questions or disagree with this plan. Thanks, %AWED 8 2037 Travis From: NSK Well Integrity Supv CPF3 and WNS Sent: Friday,July 07, 2017 8:38 AM To: 'Regg,James B (DOA)'<jim.regg@alaska.gov> Cc:Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: CD1-14 (PTD 201-038,A10 18C.006) MITIA Jim, CD1-14(PTD 201-038, A10 18C.006) is Alpine's 'blackstart'well that obtained a passing state-witnessed MITIA performed on 6/10/17 following the RWO performed in the spring. CPAI had planned to cancel the well's AA following the workover, but unfortunately we are now investigating possible continued TxIA on gas communication. Therefore, we need to still comply with the already established AA(AIO 18C.006). A10 18C.006 states CPAI shall perform an MITIA to 3000 psi every 2 years(anniversary month is June). The MIT report from 6/10/17 shows that the IA test pressure started at 3000 psi and ended at 2950 psi. The well has not been on injection since 6/19/17 while CPAI investigates the suspect TxIA on gas communication. CPAI intends to redo the witnessed MITIA after the well is brought back on stabilized injection in the event we must continue to operate CD1-14 under AIO 18C.006. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 G6t • • Prb o3 ' Regg, James B (DOA) From: Regg, James B (DOA) i Sent: Friday, July 7, 2017 2:01 PM f`( ' �/7 To: NSK Well Integrity Supv CPF3 and WNS Cc: Wallace, Chris D (DOA); Senden, R. Tyler Subject: RE: CD1-14 (PTD 201-038, Ale 18C.006) MITIA Attachments: 2012-0713_Temp_Flowback_CRU_CD1-14.pdf Our records indicate the last discussions with CPAI about CRU CD1-14 use as blackstart well was in July 2012; CPAI withdrew the request but there was discussion about establishing a backup well in the event CD1-14 had mechanical integrity concerns—see attached. Any progress? Jim Regg Supervisor, Inspections AOGCC 4 017 333 W.7th Ave,Suite 100 SCOW - Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.reggPalaska.gov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent: Friday,July 7, 2017 8:38 AM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc:Wallace, Chris D (DOA)<chris.wallace@alaska.gov>; Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: CD1-14 (PTD 201-038,A10 18C.006) MITIA Jim, CD1-14 (PTD 201-038,A10 18C.006) is Alpine's 'blackstart' well that obtained a passing state-witnessed MITIA performed on 6/10/17 following the RWO performed in the spring. CPAI had planned to cancel the well's AA following the workover, but unfortunately we are now investigating possible continued TxIA on gas communication. Therefore,we need to still comply with the already established AA(A1O 18C.006). AIO 18C.006 states CPAI shall perform an MITIA to 3000 psi every 2 years (anniversary month is June). The MIT report from 6/10/17 shows that the IA test pressure started at 3000 psi and ended at 2950 psi. The well has not been on injection since 6/19/17 while CPAI investigates the suspect TxIA on gas communication. CPAI intends to redo the witnessed MITIA after the well is brought back on stabilized injection in the event we must continue to operate CD1-14 under A10 18C.006. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. 1 aoT y • 0 CD rO _ C N a als a) x �u UCo> iQ Ql _cO `^ � _cH D a vyTO m � oO V ° u vE o n3 > W10 .7Z Q N O O -6 F. 111 r (O y (O ? QCI Q c �gz raoco N l7eLE - .J Q O u: .,_, N rl7 , . 4_' , F- Oa a1 y t C C a3 CC �+ w CU N'. 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J ,n iyi, immom r d ^ S W �..� 0 Z u E E o !l a LD<1 a a H H • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg Rel t� ( (tit!7 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD1-14 FROM: Bob Noble COLVILLE RIV UNIT CDl-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-14 API Well Number 50-103-20371-00-00 Inspector Name: Bob Noble Permit Number: 201-038-0 Inspection Date: 6/10/2017 r Insp Num: mitRCN170612081125 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD1-14 Type Inj G 1TVD 6666 Tubing 3510 ' 3510 - 3510' 3510 PTD 2010380 'Type Test SPT Test psi 1666 - IA 2180 3000 ' 2950 " 2950 - BBL Pumped: 1.4 BBL Returned: 1.3 ' OA 840 - 840 840 - 840 - Interval INITAL P/F P f Notes: Initial Post RWO �� ,� AUG 2 2? T Monday,June 19,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, June 15, 2017 7:15 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: CRU CD1-14 (PTD# 201-038) Attachments: CD1-14.pdf; CD1-14 90-day TIO.jpg Chris— CRU CD1-14(PTD#201-038) was observed with a rapid increase in IA pressure following a bleed of the IA. This well is the "black start" well for the Alpine field and currently operates under the waiver 18C.006. The well recently underwent a rig workover(Sundry 317-122) to address the T x IA communication. The Alpine field is currently involved in a planned shut-down. After the shut-down work is completed, diagnostics will be performed as soon as possible on the well. We will notify you of the results of those diagnostics and a path forward if a problem is identified. A 90-day TIO plot and wellbore schematic are attached. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUN 2 32017, • l i L3 LJ 0 V C] IJ f t -4 1 I I I i ,� A C L.. r 1 - ai....z.,1 __ & n .. N C I 0 u 1 c .7 / - I-- E E $ 0 U 4 iii is 4) ® C v Q 1 ,...,. i ti er qr. 0 -. N itgi IIII I ,~ iH8 I V ice' g iLL = tnd 3 N CM W M Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday, May 19, 2017 3:04 PM To: NSK Well Integrity Supv CPF3 and WNS Cc: Senden, R.Tyler; Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: RE:CRU CD1-14 (PTD#201-038, Sundry#317-122) Travis, Thank you for providing the rig performed MITIA. A delay of the stabilized injection witnessed MITIA to approximately June 6 is acceptable to have the well completed with the other pad tests. Remember the requirement of 18C.006 to shut in the well if any pressure monitoring indicates a lack of mechanical integrity. Also might be worth reviewing the pressures required under that AIO 18C.006. Once the witnessed MITIA successfully completes the workover,a request to cancel AIO 18C.006 would seem appropriate. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent: Friday, May 19, 2017 2:50 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE:CRU CD1-14 (PTD#201-038,Sundry#317-122) SCANNED (,tA', 3 ut ?AI. Hello Chris— Yes,the rig performed a test of the IA to 2500 psi that passed. I have attached the charted test of the tubing and IA from the workover here. Thanks, Travis From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, May 19,2017 2:37 PM To: NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> 1 e , Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]RE: CRU CD1-14(PTD#201-038, Sundry#317-122) Travis, Was there a rig performed MITIA completed at all and if so can you confirm a good test? Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent: Friday, May 19, 2017 11:16 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD1-14 (PTD#201-038,Sundry#317-122) Chris— The post-rig wellwork for CRU CD1-14(PTD#201-038,Sundry#317-122) is nearly completed following a rig workover to swap tubing. This well serves as the"Black Start"well for the Alpine facility, providing fuel gas in the event of shut- downs. The path forward for preparing the well for service includes an injection and production test,consisting of the following outline steps: 1. Flowback any remaining workover fluids 2. Wait at least 12 hours post-flowback, perform Injection Test: a. 1.5 MMSCFD for 12 hours b. 3.0 MMSCFD for 24 hours c. 4.0 MMSCFD for 48 hours 3. Wait at least 12 hours post-injection, perform Production Test: a. 2 MMSCFD for 2 hours b. 4 MMSCFD for 2 hours c. 6 MMSCFD for 2 hours d. 8 MMSCFD for 2 hours After this,the well will be operationally ready for gas injection or use for black start purposes. CPAI proposes putting the well on gas injection after this work is completed and waiting to perform the required State-witnessed MIT-IA until the full pad testing of CD1 is performed in June. The CD1 pad testing is tentatively scheduled for June 6, 2017. Please advise if this delay of the witnessed MIT-IA is acceptable to the AOGCC. Thank you very much, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 RECEIVED STATE OF ALASKA • AIDA OIL AND GAS CONSERVATION COMMI N MAY 1 6 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 201-038 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic LI Service 2 6.API Number: 99510 50-103-20371-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25559 CRU CD1-14 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 18,939 feet Plugs measured None feet true vertical 6,814 feet Junk measured None feet Effective Depth measured 18,939 feet Packer measured 13141, 13365 feet true vertical 6,814 feet true vertical 6563,6666 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 " 115' MD 115 SURFACE 3,550 feet 9 5/8" 3,587' MD 2366 INTERMEDIATE 14,039 feet 7 " 14,073' MD 6855 OPEN HOLE 4,866 feet 6 1/8" 18,939' MD 6814 SCANNEDU N ` 4 17 Perforation Depth Measured depth N/A feet Tubing(size,grade,measured and true vertical depth) 4.5" L-80 13,420' MD 6,690'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER 4-1/2"PREMIER PA 13,141'MD 6,563'TVD PACKER-BAKER S-3 PACKER 13,365' MD 6,666'TVD SSSV -NIPPLE, BP6i HYD 2,293' MD 1,829'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 0 9000 0 1500 3400 Subsequent to operation: o 9000 0 50 3350 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas D WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 2 WINJ 0 WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-122 Contact Name: Sara Heskin Authorized Name: Sara Heskin Contact Email: sara.heskin@conocophillips.com Authorized Title: Assoc.Wells Engineer SWIO.Ili - I / j7 Contact Phone: (907)265-1027 Authorized Signature: Date: / Form 10-404 Revised 4/2017 v-1—L ,1,711-7- Submit Original Only 4e *lT > ?3DMS 1. -MAY 1 7 2017 =` Operations Summary (with Timelog Depths) tz .rte _ CD1-14 C c®Phithps Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS) 4/8/2017 4/8/2017 12.00 MIRU MOVE MOB P Pull GIS away from pits,back pits, 0.0 0.0 00:00 12:00 motors and pipe shed away from sub. Remove squeeze manifold and rigging from cellar walls.Skid rig floor.GIS, Pits and Motors depart CD3 @ 10:00 hrs. 4/8/2017 4/9/2017 12.00 MIRU MOVE MOB P Move GIS,Pits and motors from CD3 0.0 0.0 12:00 00:00 to CD1, 11.5 miles.Arrive on CD1 @ 23:00 hrs.Move Sub down to CD3 ice pad and remove wind walls. 4/9/2017 4/9/2017 6.00 MIRU MOVE MOB P Move Sub and pipeshed from CD3 to 0.0 0.0 00:00 06:00 mile 3 on ice road,crossed bridges. Continue cleaning up around CD3- 111A,handover well. 4/9/2017 4/9/2017 3.00 MIRU MOVE RGRP T Shut down due faulty solenoid on sub 0.0 0.0 06:00 09:00 moving system.Troubleshoot and repair. 4/9/2017 4/9/2017 3.00 MIRU MOVE MOB P Continue moving sub and pipeshed 0.0 0.0 09:00 12:00 down ice road towards CD2. 700 bbl 12.8 ppg WARP KWF mixed and ready for displacement. 4/9/2017 4/9/2017 8.00 MIRU MOVE MOB P Move sub and pipeshed from ice road 0.0 0.0 12:00 20:00 to CD1 pad,mile 11. Give 48 hr notice to AOGCC for upcoming BOP test. 4/9/2017 4/10/2017 4.00 MIRU MOVE MOB P Move down CD1 access,around well 0.0 0.0 20:00 00:00 row and line up to CD1-14.Ensure adjacet wells are shut in. 4/10/2017 4/10/2017 1.00 MIRU MOVE MOB P Raise windwalls/stompers to spot 0.0 0.0 00:00 01:00 over well. 4/10/2017 4/10/2017 1.50 MIRU MOVE MOB P PJSM,Spot sub over CD1-14.Shim 0.0 0.0 01:00 02:30 and set down. 4/10/2017 4/10/2017 1.50 MIRU MOVE MOB P Lower stompers/windwalls. 0.0 0.0 02:30 04:00 4/10/2017 4/10/2017 1.00 MIRU MOVE MOB P Remove safety plates,skid rig floor to 0.0 0.0 04:00 05:00 drilling position. SIMOPS-Move pits/motors into position to mate up. 4/10/2017 4/10/2017 1.00 MIRU MOVE MOB P Make up pits/motor complex. 0.0 0.0 05:00 06:00 4/10/2017 4/10/2017 3.00 MIRU MOVE RURD P Spot and make up pipe shed and ball 0.0 0.0 06:00 09:00 mill. SIMOPS-Hook up steam,water, diesel,electrical.Wrap cellar drillers side wind wall with visqueen due CD1- 15 flowline height.(Unable to lower windwall fully) 4/10/2017 4/10/2017 4.00 MIRU MOVE RURD P Work on rig acceptance checklist,take 0.0 0.0 09:00 13:00 on 152 bbl 12.8 ppg WARP KWF. Tested rig gas alarms. Rig on highline power @ 10:30 hrs. Accept rig @ 13:00 hrs. 4/10/2017 4/10/2017 2.00 MIRU WELCTL RURD P Rig up circulating lines to choke skid 0.0 0.0 13:00 15:00 and tiger tank.Rig up tree work platform. 4/10/2017 4/10/2017 1.00 MIRU WELCTL MPSP P Rig up and test lubricator to 3500 psi. 0.0 0.0 15:00 16:00 Pull BPV.Lay down lubricator and install 1502 tree swedge. Tubing=700 psi, IA=1100 psi,0A=450 psi. Page 1/7 Report Printed: 5/16/2017 • • 0'$°" Operations Summary (with Timelog Depths) --.-1.,„,:(t',; CD1-14 ConocoPhitiips Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/10/2017 4/10/2017 1.50 MIRU WELCTL RURD P PJSM,Steam and re-torque all 0.0 0.0 16:00 17:30 hardline connections.Blow down and pressure test with rig air.Flood lines and pressure test to 3500 psi to tiger tank. 4/10/2017 4/10/2017 1.00 MIRU WELCTL KLWL P Bleed off tubing pressure to tiger tank. 0.0 0.0 17:30 18:30 Pump seawater down IA taking returns up tubing to clear diesel cap. Pumped 45 bbl @ 3 bpm, ICP=290 psi,FCP=590 psi. Recover 41 bbl diesel for storage and re-use. 4/10/2017 4/10/2017 3.00 MIRU WELCTL KLWL P Pump down tubing,returns up IA 0.0 0.0 18:30 21:30 displace to 12.8 ppg WARP Kill weight fluid.Pump 35 bbl Viscosified seawater spacer,chase with 12.8 ppg KWF @ 3 bpm,200 psi ICP strapping return at tiger tank for bbl in/out.At 200 bbl pumped,apply 320 psi back pressure with choke skid to mitigate influx as tiger tank loads to vac truck. FCP with full open choke 640 psi @ 452 bbl 12.8 ppg pumped.Obtain sample @ choke skid,shut down, blow down outside lines and equipment. 4/10/2017 4/10/2017 0.50 MIRU WELCTL CIRC P Line up returns to pits,circulate @ 2 0.0 0.0 21:30 22:00 bpm,450 psi until good 12.8 ppg in/out. 4/10/2017 4/10/2017 1.50 MIRU WELCTL OWFF P Monitor IA and tubing for flow until 0.0 0.0 22:00 23:30 static for 30 minutes.Observe U- tubing and thermal expansion for 1 hrs,tapering to static.Observe well static for 30 minutes. 4/10/2017 4/11/2017 0.50 MIRU WELCTL RURD P Blow down surface lines,rig down 0.0 0.0 23:30 00:00 circulating equipment in cellar. SIMOPS-bleed down control lines. 4/11/2017 4/11/2017 1.00 MIRU WHDBOP MPSP P Rig down circ lines in cellar,FMC 0.0 0.0 00:00 01:00 installed HP-BPV. 4/11/2017 4/11/2017 2.00 MIRU WHDBOP NUND P Bleed off tree/adapter void and control 0.0 0.0 01:00 03:00 lines. N/D tree/adapter,terminate control lines. SIMOPS-Shut in CD1-13,Bleed off 1200 psi from CD1-15 flowline/header. 4/11/2017 4/11/2017 2.00 MIRU WHDBOP NUND P N/U BOPE,rig up flow box,Orbit 0.0 0.0 03:00 05:00 valve,clamps,flow line,hole fill line, bleeder lines and install trip nipple. 4/11/2017 4/11/2017 1.00 MIRU WHDBOP RURD P MU head pin to 4-1/2 Test jt to FMC 0.0 0.0 05:00 06:00 Blanking plug. RU testing equip. 4/11/2017 4/11/2017 1.50 MIRU WHDBOP RGRP T Blow down choke and kill lines - 0.0 0.0 06:00 07:30 trouble shoot BOPE remote panels 4/11/2017 4/11/2017 0.50 MIRU WHDBOP RURD P Fill stack,choke and kill lines w/Fresh 0.0 0.0 07:30 08:00 water-purge air from system Page 2/7 Report Printed: 5/16/2017 • • Operations Summary (with Timelog Depths) rpt 4r CD1-14 al iiilp Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Tune End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 4/11/2017 4/11/2017 6.00 MIRU WHDBOP BOPE P 24 hour notice was given toAOGCC 0.0 0.0 08:00 14:00 on 4-10-17 @ 17:11 hrs. Initial BOP test was witnessed by Brian Bixby. With 4'/z'test joint, Test Annular to 250/2500 psi,All Rams test to 250/ 4,000 Choke valves#1,12,13,14,Upper IBOP/Upper VBR,4"Demco kill/CV #9,11,lower IBOP,HCR kill/CV #5,8,10/CV#4,6,7/CV#2/HCR Choke/Manual choke and kill/Lower VBR's. Upper VBR's,4"XT-39 Dart/ Lower VBR's,XT-39 FOSV. Perform accumulator function test. System pressure=2800 psi,Manifold pressure=1450 psi,Annular pressure=850 psi. System pressure after functioning all rams and HCR's=1450 psi. 200 psi attained @ 28 sec, Full system recovery @ 154 sec. 4 bottle N2 average=1940 psi. Operate remote stations. Tested gas detectors,function flow meter,check PVT alarms. 4/11/2017 4/11/2017 1.00 MIRU WHDBOP RURD P Blow down and Rig down all testing 0.0 0.0 14:00 15:00 equipment and pull BPV. 4/11/2017 4/11/2017 1.50 COMPZN RPCOMP PULL P MU landing joint,cross over sub, 13,339.0 13,329.0 15:00 16:30 FOSV,with handling pup and screw in Top drive. BOLDS,un land hanger @ 154k,observe 168k free travel. 4/11/2017 4/11/2017 1.50 COMPZN RPCOMP CIRC P Break circulation and stage up 3 bpm 13,329.0 13,329.0 16:30 18:00 @ 680 psi with 63%flow. At bottoms up,observe gas increase to 1,453 units and flow out remained the same with No gain or Loss. Continue to circulate and @ 393 bbls pumped, observed gas spike of 3,937 units, with flow increase to 73%. Pump pressure reduced to 550 psi with stroke rate increase. Shut down pumps and monitor well for flow- observed flow at flow line @ 18:00 hrs. Shut well in using the Annular preventer. 4/11/2017 4/11/2017 0.50 COMPZN RPCOMP OWFF T Monitor pressure build up for 30 13,329.0 13,329.0 18:00 18:30 minutes. SITP=60 psi;SICP=40 psi.w/6 bbl pit gain. 4/11/2017 4/11/2017 2.50 COMPZN RPCOMP CIRC T Circulate thriough the gas buster using 13,329.0 13,329.0 18:30 21:00 the drillers method staged pump rate up to 3 bpm and pump 460 bbls w/ICP of 650 psi, Increased BHP to 780 psi and maintained. 4/11/2017 4/11/2017 1.00 COMPZN RPCOMP OWFF T Monitor shut in pressures-SITP=220 13,329.0 13,329.0 21:00 22:00 psi,SICP=220 psi. Slowly bleed off pressures with minimal pit gain till full open choke-observe slight flow@ U- tube Page 3/7 Report Printed: 5/16/2017 • • Operations Summary (with Timelog Depths) CD1-14 ConocoPhillips Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) s End Depth(ftKB) 4/11/2017 4/11/2017 1.00 COMPZN RPCOMP CIRC T CBU @ 3.5 bpm @ 590 psi trough full 13,329.0 13,329.0 22:00 23:00 open choke while routing thru Gas buster with 260 bbls-No Gain/No Loss. 4/11/2017 4/12/2017 1.00 COMPZN RPCOMP CIRC T Continue to circulate through the gas 13,329.0 13,329.0 23:00 00:00 buster and increase mud weight to13 ppg from 12.8 ppg 4/12/2017 4/12/2017 2.50 COMPZN RPCOMP CIRC T Continue to circulate through the gas 13,329.0 13,329.0 00:00 02:30 buster and increase mud weight to13.2 ppg in and 12.9 ppg out. Shut down and open annular. 4/12/2017 4/12/2017 2.50 COMPZN RPCOMP CIRC T Begin circulating back to the pit 13,329.0 13,329.0 02:30 05:00 system down the flow line rather than the degasser. Increase circulating rate from 3.5 to 8 bpm @ 660 psi to 1,640 psi. While continuing to increase mud weight to 13.6 ppg. 4/12/2017 4/12/2017 2.75 COMPZN RPCOMP CIRC T Continue circulating back to the pit 13,329.0 13,329.0 05:00 07:45 system down the flow line,Circulating at 8 bpm @ 1,734 psi. At 05:30 mud wt in 13.5 ppg/mud wt out 13.5 ppg. Dust up to 13.6 ppg in and out. Shut down pumps 4/12/2017 4/12/2017 0.50 COMPZN RPCOMP OWFF T Monitor well for flow for 30 minutes- 13,329.0 13,329.0 07:45 08:15 Static Stroke pipe 10 x's,no swabbing observed 4/12/2017 4/12/2017 1.25 COMPZN RPCOMP CIRC T CBU @ 8 bpm @1,800 psi,no gas 13,329.0 13,329.0 08:15 09:30 seen at bottoms up. 4/12/2017 4/12/2017 0.50 COMPZN RPCOMP OWFF T Monitor well for flow for 30 minutes- 13,329.0 13,329.0 09:30 10:00 Static 4/12/2017 4/12/2017 0.50 COMPZN RPCOMP PULL P POOH laying down TBG hanger, 13,329.0 13,300.0 10:00 10:30 Landing joint and FOSV. Change out elevators and RU TBG equipment. 4/12/2017 4/13/2017 13.50 COMPZN RPCOMP PULL P POOH laying down 4-1/2 IBTM De 13,300.0 4,341.0 10:30 00:00 completion tubing and spooling chem inj.line and SSSV control line- Recovered 56 of 57 SS Bands.- missing lowest band at the BP-6i Nipple. Laid down 207 joints of the 306 ran. 90K Up wt,90K Dn wt 4/13/2017 4/13/2017 5.25 COMPZN RPCOMP PULL P Continue to POOH laying down 4-1/2 4,341.0 0.0 00:00 05:15 IBTM De completion tubing from 4,341 -ft to cut. Cut joint was 27.67-ft long and was in perfect formation of 4-1/2" OD-with No swelling. 4/13/2017 4/13/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow-Static 0.0 05:15 05:45 4/13/2017 4/13/2017 0.50 COMPZN WELLPR BOPE P Drain BOP stack-Set test plug and fill 05:45 06:15 stack with fresh water. 4/13/2017 4/13/2017 1.25 COMPZN WELLPR BOPE P Purge air from system. test Annular 06:15 07:30 with 4-1/2 Test Joint to 250/3,500 psi. Test valve#5 on CM to 250/ 4,000 psi-Good Test,All tests on chart and Witness was waived by Brian Bixby 4/13/2017 4/13/2017 0.50 COMPZN WELLPR BOPE P Drain stack,Pull test plug and install 07:30 08:00 wear ring. Page 4/7 Report Printed: 5/16/2017 • • Operations Summary (with Timelog Depths) z r CD1-14 ConocaPhiilips Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Codei. Time P-T-X Operation (EKE) End Depth(ftKB) 4/13/2017 4/13/2017 1.00 COMPZN WELLPR PRTS P Close Blind rams and pressure test 7" 08:00 09:00 Casing to 1,000 psi(1.7 BBLS)for 15 minutes on chart-Good Test. Bleed off pressure and open pipe rams. 4/13/2017 4/13/2017 0.50 COMPZN WELLPR OWFF P Monitor well for flow-Slightly aerated, 09:00 09:30 but static 4/13/2017 4/13/2017 1.25 COMPZN RPCOMP RURD P RU Doyon Casing equipment for 09:30 10:45 running tubular's. 4/13/2017 4/13/2017 8.75 COMPZN RPCOMP PUTB P RIH w/4-1/2, 12.6#,L-80, R3 Tenaris 0.0 6,428.0 10:45 19:30 Hydril Wedge 563 completion Tubing as per detail to 6,428-ft. Filling Tubing every 400-ft 4/13/2017 4/13/2017 1.50 COMPZN RPCOMP WAIT T Suspended running operations while 6,428.0 6,428.0 19:30 21:00 trouble shooting-Found that the upper 2,300-ft of completion was unable to be drifted to accommodate the turned down 3.885"lock for the BP6-I nipple The published HYD563 ID is 3.908".Unfortunately the lock assembly is unable to drift and we do not want to risk being unable to pull the lock or be unable to install the SSSV into the nipple profile post-rig. 4/13/2017 4/14/2017 3.00 COMPZN RPCOMP PUTB P Continue to RIH for total of 200 jts of 4 6,428.0 8,266.0 21:00 00:00 -1/2, 12.6#, L-80,R3 Tenaris Hydril Wedge 563 completion Tubing as per detail from 6,428-ft to 8,266-ft. Filling Tubing every 400-ft. 82K Dn wt 4/14/2017 4/14/2017 3.00 COMPZN RPCOMP PUTB P Continue to RIH for total of 269 jts of 4 8,266.0 11,038.0 00:00 03:00 -1/2, 12.6#,L-80,R3 Tenaris Hydril Wedge 563 completion Tubing as per detail from 8,266-ft to 11,038-ft. Filling Tubing every 400-ft. 82K Dn wt 4/14/2017 4/14/2017 2.00 COMPZN RPCOMP OTHR T Offload pipe shed of the 4-1/2 Wedge 11,038.0 11,038.0 03:00 05:00 563 TBG and reload with 60 joints 4- 1/2, 12.6#,TXP, R3 Tubing.Strap and Drift to 3.90" 4/14/2017 4/14/2017 3.50 COMPZN RPCOMP PUTB P PU Chem injection/BP-6i Hydraulic 11,038.0 11,038.0 05:00 08:30 Nipple assembly,drift with ball and rod,RU sheaves and cannon clamping tools. MU control and injection lines to equipment and PT injection line to 6,700 psi for 15 minutes and control line to 2,500 psi 4/14/2017 4/14/2017 8.50 COMPZN RPCOMP PUTB P Continue to RIH w/4-1/2, 12.6#,TXP, 11,038.0 13,347.0 08:30 17:00 R3 Tubing from 11,038-ft to 13,347-ft and sheared OS pins @ 13,343-ft with 15.5K set down weight. MU WR retrieval tool,recover wear ring and PU 20.23-ft of pup jts below 1st full joint below TBG hanger. MU landing jt and Orient TBG hanger,terminate control and injection lines. Feed thru TBG hanger and PT to 5,000 psi- good test. installing 55-4.500-A-11 Dual channel Xcplg Cannon clamps and 3 SS bands. Page 5/7 Report Printed: 5/16/2017 • • 0 Operations Summary (with Timelog Depths) CD1-14 ConocoPhillips Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 4/14/2017 4/14/2017 2.50 COMPZN RPCOMP CRIH P Break Circulation at 1 bpm at 760 psi, 13,327.0 13,327.0 17:00 19:30 spot 21 bbls of 13.6 ppg CI WARP KWF. Displace with 190 bbls of 13.6 KWF to balance @ 2 bpm @ 720 psi. 4/14/2017 4/14/2017 0.75 COMPZN RPCOMP THGR P Drain stack and land TBG hanger, 13,327.0 13,346.7 19:30 20:15 RILDS, -RD Control line sheaves. 4/14/2017 4/14/2017 1.00 COMPZN RPCOMP PRTS P Test Upper seals to 250 psi for 5 20:15 21:15 minutes and 5,000 psi for 10 minutes- good test. Pressure DH pump thru plug to 1,000 psi for 10 minutes-good test. Break out head pin and drop 1- 1/4 ball x 9-ft roller stem with 1-3/8" Fishing neck assembly. 4/14/2017 4/14/2017 2.50 COMPZN RPCOMP PACK P After 35 minutes of waiting for ball to 21:15 23:45 drop,PT TBG to 4,000 psi and set 4- 1/2 x 7"Baker Premier packer @ 13,141-ft. Hold pressure on tbg for 30 minutes and chart the same.-good test,bleed back pressure to 1,750 psi. Pressure up on the IA to 2,500 psi for 30 minutes-good test. Bleed IA pressure off to zero and Bleed Tbg pressure to zero. Pressure up on the IA to 2,500 psi and SOV didn't shear- Pressure up Tbg to 1,500 psi and dump,SOV sheared. 4/14/2017 4/15/2017 0.25 COMPZN RPCOMP CIRC P Reverse circulate 42 bbl spacer at 2.8 23:45 00:00 bpm @ 2,340 psi to displace 13.6 ppg KWF with Sea water. 4/15/2017 4/15/2017 3.75 COMPZN RPCOMP CIRC P Continue to displace 460 bbls of 13.6 00:00 03:45 ppg KWF with 552 bbls of sea water at 3 bpm or 2,500 psi max. 4/15/2017 4/15/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow-static 03:45 04:00 4/15/2017 4/15/2017 1.00 COMPZN RPCOMP PRTS P Combo pressure test to 3,500 psi with 04:00 05:00 6 bbls for 30 minutes- 4/15/2017 4/15/2017 0.25 COMPZN RPCOMP RURD P RD testing equipment and pull landing 05:00 05:15 jt. 4/15/2017 4/15/2017 0.75 COMPZN WHDBOP MPSP P Install BPV with dart in place,install 05:15 06:00 landing joint,pressure test at 1,000 psi from below for 10 minutes. 4/15/2017 4/15/2017 0.25 COMPZN WHDBOP OTHR P Pull landing jt. 06:00 06:15 4/15/2017 4/15/2017 3.25 COMPZN WHDBOP WWWH P Install 4"DP elevators,PU,MU Stack 06:15 09:30 washing tool. Wash stack at 10 bpm @ 20 psi. RD Stack washing tool. Drain choke and kill lines,ND BOPE 4/15/2017 4/15/2017 2.50 COMPZN WHDBOP THGR P Tie in Chem injection line and SSSV 09:30 12:00 control line to the Well head ports 4/15/2017 4/15/2017 1.00 COMPZN WHDBOP MPSP P Install Dart into BPV,and Install 12:00 13:00 SBMS Page 6/7 Report Printed: 5/16/2017 • ! Operations Summary (with Timelog Depths) CD1-14 ComccsPnitijps Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(tir) Phase. Op Code ActivityCode Time P-T-X Operation (ftKB) End Depth(ftKB) 4/15/2017 4/15/2017 7.00 COMPZN WHDBOP NUND T NU Tree and Adapter-Test Adapter 13:00 20:00 flange to 250/5,000 psi-seen leak at 3/8"injection control line. ND Tree and adapter. Splice and fix control line-found control line to be out of round and Farrow was unable to seal. Went on Generator @ 16:50 hrs 4/15/2017 4/15/2017 1.25 COMPZN WHDBOP NUND T NU Tree and Adapter Flange-Test @ 20:00 21:15 250/5,000 psi for 10 minutes.-Good test. 4/15/2017 4/15/2017 2.25 COMPZN WHDBOP PRTS P Fill tree with diesel and Pressure test 21:15 23:30 the same at 250/5,000 psi for 10 minutes -good test. 4/15/2017 4/16/2017 0.50 COMPZN WHDBOP MPSP P Test Lubricator to 1000 psi,Pull test 23:30 00:00 dartand BPV 4/16/2017 4/16/2017 0.50 COMPZN WHDBOP MPSP P Test Lubricator to 1000 psi,Pull test 0.0 0.0 00:00 00:30 dartand BPV 4/16/2017 4/16/2017 1.50 COMPZN WHDBOP SEQP P R/U lines to reverse out diesel to the 0.0 0.0 00:30 02:00 tiger tank. Test lines to 2000 psi. 4/16/2017 4/16/2017 1.75 COMPZN WHDBOP CIRC P Circulate out diesel with 485 bbl at 4 0.0 0.0 02:00 03:45 bpm, 1900-1360 psi. 4/16/2017 4/16/2017 0.50 COMPZN WHDBOP OTHR P B/D lines and R/D tubing hoses. 0.0 0.0 03:45 04:15 4/16/2017 4/16/2017 1.25 COMPZN WHDBOP MPSP P R/U lubricator and install BPV. 0.0 0.0 04:15 05:30 Pressure test from the IA to 1000 psi for 15 min and chart. Bleed off and recorded final pressures. IA=200 psi, OA=625 psi,and TBG=0 psi. WELL SECURE 4/16/2017 4/16/2017 2.00 DEMOB MOVE RURD P B/D lines,empty cellar,disconnect rig 0.0 0.0 05:30 07:30 lines,air,water,power.... 4/16/2017 4/16/2017 3.00 DEMOB MOVE MOB P Disconnect electricity and pull pits, 0.0 0.0 07:30 10:30 motors,pipe shed,and ball mill from sub. 4/16/2017 4/16/2017 1.50 DEMOB MOVE MOB P Skid sub away from well. 0.0 0.0 10:30 12:00 Page 7/7 Report Printed: 5/16/2017 a WNS CD1-14 ConocoPhillips Well Attribu Max Angle D TD lt't lfet.lt1D. Wellbore API/UWI Field Name Wellbore Status 'ncl C) MD(ftKB) -Act Btm(ftKB) Cawco6higi,,':'" 501032037100 ALPINE INJ 95.01 14,181.99 18,939.0 1- I_ ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD1-14,5/16/20173.56:55 PM SSSV:NIPPLE Last WO: 4/16/2017 43.70 5/11/2001 Verocal schemapP(man.. Annotation Depth(Itch) End Date Annotation Last Mod By End Date Last Tag'SLM Rev Reason:RECOMPLETION,GLV C/O pproven 5/16/2017 Hanger;31 9 -...-- Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.Grade Top Thread CONDUCTOR 16 15.062 37.0 115.0 115.0 62.58 H-40 WELDED !j Caning Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... W1/Len(I...Grade Top Thread SURFACE 9 5/8 8.921_ 36.8 3,586.5 2,366.0 40.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.3 14,073.1 6,855.1 26.00 L-80 BTCM I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread III OPEN HOLE 6 1/8 14,073.0 18,939.0 6,813.7 Tubing Strings Tubin Descri t Shin Ma...IDTopftKB Set Depth ft...Set Depth ND Wt Ib/ft Grade TopConnection �� \►�\1 9 Pion 9 (in) I ) P ( P (TVD) ( I TUBING RWO 2017 4 1/2 4.000 31.9 13,346.7 6,657.8 11.60 L-80 Hydril 563 I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not C) Item Des Com (in) CONDUCTOR;37.0-1150 31.9 31.9' 0.12 Hanger FMC 4-1/2"Tubing Hanger Drifted to 3.90" 4.000 2,292.5 1,829.0 65.39'NIPPLE 4.5"X 3.875"BP-6i HYD NIPPLE(12.68,L-80,Hydril 3.875 I563 Box Pin) I 2,296.9 1,830.8 65.43 NIPPLE 4.5"DCIN II,CHEMICAL INJECTION ASSEMBLY(12.68, 3.868 L-80,Hydril 563 Boxx Pin) NIPPLE,2,292.5 im 13,141.2 6,563.4 61.97'PACKER Baker 4-1/2"Premier Packer 3.880 13,211.3 6,596.0- 62.54 NIPPLE 4.5"DB6 E Landing Nipple w/3.813"DB6E 3.813 13,270.7 6,623.2 62.81 NIPPLE 4.5"3.812 X nipple(12.68,L-80,Hydril 563 Box x Pin) 3.812 NIPPLE;2,296.9 13,340.0 6,654.7- 63.18 Poor Boy Baker Non-Sealing Overshot 4.750 Overshot Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ibfft) Grade Top Connection • TUBING ORIGINAL 41/2 3.958 13,339.0 13,421.3 6,690.8 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 3.875 13,365.1 6,666.0 63.49 PACKER BAKER S-3 PACKER 13,409.1 6,685.4 64.04 NIPPLE HES XN NIPPLE 3.725 SURFACE;360-3,588.5 13,420.0 6,690.2 64.17 WLEG WIRELINE GUIDE 3.875 I Mandrel Inserts St an GAS LIFT;13,073.4 on Top(NO) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 13,073.4 6,531.2 CamcoKBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/23/2017 Notes:General&Safety End Date Annotation 6/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;13,141.2 12/11/2015 NOTE'Waiver TxIA Communication I I NIPPLE;13,211.3 I I I NIPPLE;13,270.7 I I I I Poor Boy Overshot,13,340.0 ..I PACKER;13,365.0 r '$p I aaa NIPPLE;13,409.1 IMF WLEG,13,420.011 . INTERMEDIATE;34.3-14,073.1 „-, OPEN HOLE;14,073.0-18,939.0 • p TD.b/ - 0 3 g Loepp, Victoria T (DOA) From: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Sent: Wednesday,April 1.2,2017 4:27 PM To: Herbert, Frederick 0; Kanady, Randall B; Heskin, Sara E; Buck, Brian R; DOA AOGCC Prudhoe Bay; Loepp,Victoria T(DOA) Cc: Haggerty-Sherrod,Ann(Northland Staffing Services); Conklin,Amy A(Swift Technical Services LLC); Beat,Andrew T; Phillips, Ron L Subject: CPAI CD1-14 PTD#201-038 RWO BOPE Usage Notification Attachments: CD1-14 BOP Use Notification.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Please find attached letter to follow up CPAI's email notification of BOPE use on 4/11/2017 on Doyon 19. Please let me know if you have any questions. Thank you, Sara,Heig / Associate Wells Engineer North Slope Workover Engineering ConocoPhillips Alaska Office: 907-265-1027 %ANNE° r' I sara.heskin@conocophillips.com 1 • • Con � ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 12,2017 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003,this letter is to follow up the email notification of BOPE usage on Doyon 19 with a written report. Time of BOPE Use:4/11/2017 at 18:00 hours Well Location:CD1-14 API Number:50-103-203-7100 Rig Name:Doyon 19 PTD Number: 201-038 Operator Contact:Sara Heskin(o)907-265-1027(c)907-331-7514 Sara.E.Heskin@conocophillips.com Operations Summary: On 4/11/2017,the rig released the tubing hanger and then picked up from a pre-rig tubing cut with free tubing movement at 168Klbs block weight.The well was then circulated,staging up to 3 bpm at 680 psi.At bottoms up,a gas increase of 1,453 units was observed with no change in return rate.At the time,the fluid in the hole was 12.8 ppg mud(kill-weight according to pre-rig pressure diagnostics),and a pre-rig test confirmed integrity of the packer and plug combination. After 393 bbls of 12.8 ppg mud were pumped in the circulation,the rig observed a gas spike of 3,937 units. Flow returns increased from 63%to 73%.The pumps were shut in and the well was monitored for flow.Flow was observed at the flowline at 18:00 hrs.The well was promptly shut-in using the annular preventer.An initial 2 bbl pit gain was observed.The shut-in tubing pressure(SITP)built to 60 psi and the shut-in casing pressure(SICP)built to 40 psi in 30 minutes. The well was then circulated through the gas buster using the drillers method,staging up to 3 bpm.The rig pumped 460 bbls with an initial circulating pressure of 650 psi.It increased to 780 psi while pumping,and that pressure was maintained through the circulation.After circulation,220 psi was trapped in the system. The pressure was slowly bled off with minimal pit gain to a full open choke.Minimal flow was observed. The rig circulated a bottoms-up at 3.5 bpm through a full open choke through the gas buster with no gain or loss. The rig calculated the new kill weight fluid to be 13.0 ppg based on the 60 psi SITP.An additional 0.6 ppg was added to allow adequate trip margin to commence with workover operations and lay down the tubing.The rig then began to weight up the mud from 12.8 ppg to 13.6 ppg in 0.2 ppg increments. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 The annular will be re-tested when the tubing gets pulled out of the hole.Future operations were altered to keep the kill weight fluid in the hole in the well until new barriers are in place after landing the new tubing hanger. If you have any questions or require any further information,please contact me at 265-1027. Sincerely, ara Heskin Wells Engineer CPAI Drilling and Wells ' OFT • tvyy�� 9 THE STATE Alaska Oil and Gas �i"d�-�� of111 SK1 Conservation Commission _ 5 333 West Seventh Avenue k" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ra. 0 �- � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sara Heskin Assoc. Wells Engineer ConocoPhillips Alaska, Inc. %ANNE) APRL'J. P.O. Box 100360 Anchorage,AK 99510 Re: Colville River Field,Alpine Oil Pool, CRU CD 1-14 Permit to Drill Number: 201-038 Sundry Number: 317-122 Dear Ms. Heskin: 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, Cathycviev Foerster Chair DATED this `day of April,2017. RBDMS l " 7'" . 4 2017 • III • RECEIVED • STATE OF ALASKA R 2 17 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 0i- 4 / 7 20 AAC 25.280 AOG 1.Type of Request Abandon r Plug Perforations r Fracture Stimulate r Repair Well pi` Operations Shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing F Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development r 201-038 3.Address: 6.API Numbers-0 —,03_ '1 03?1_00 P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service ' 50 10320 37-49-00 ,,''`` 7.If perforating: 8.Well Name and Number: �"�J What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes r No 17 CRU CD1-14 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25559 • Colville River Field/Alpine 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): 18,939' - 6,814' 3765 N/A 12112 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 115' 115' Surface 3,550' 9.625" 3,587' 2,366' Intermediate 14,039' 7" 14,073' 6,855' Open Hole 4,866' 6.125" 18939' 6,814' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A 4.500" L-80 13,421' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER S-3 PACKER MD=13365 TVD=6666 SSSV-WRDP-2 BAL-O MD=2298 TVD=1831 12.Attachments: Proposal Summary Q • Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory r Stratigraphic r Development r Service P- 14.Estimated Date for 15.Well Status after proposed work: to 4/6/2017 Commencing Operations: OIL r WINJ r 1 WDSPL r Suspended r 16.Verbal Approval: Date: GAS I WAG iv GSTOR , SPLUG r Commission Representative: GINJ Op Shutdown 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 Sara Heskin @ 265-1027 Email sara.heskin@conocophillips.com Printed Name Sara Heskin Title Assoc.Wells Engineer 300N) (hei " 3g3faol Signature Phone Phone:265-1027 ate COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317— 22 Plug Integrity ❑ BOP Test t" Mechanical Integrity Test Location Clearance ❑ 4--.6 y I`(Itq Other: 80 p 1---r-51- 1.7Y-1.551Jt'G 'fa 40110 p 4 wGt 1 vtr /5 y rte, si trd i--6) a !o w G-1p ckC Post Initial Injection MIT Req'd? Yes 15---No ❑ b&1/a cc-C1 ti 8Z o s a be r fh f,-93 o f ti-2.- /� .he, lz rntrr- ViI Spacing Exception Required? Yes El No 7f Subsequent Form Required: `p_4 b 4- �/' r D 4,C 2 4/2 lb V APPROVED BY Approved by: P 4/�— COMMISSIONER THE COMMISSION Date:C� -- 7 ?lib 304 r7— { 14 D A' /'- `Z�� Submit Form and Form 10-403 Revised 11/2015 O '\ cJIaYW c valid for 12 months from the date of approval. A �t�q,ents n Formate RBDMS �� rt • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 MAR 2 3 Z017 ANCHORAGE,ALASKA 99510-0360 j��(� Aj GCC March,23rd 2017 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. (CPAI) hereby applies for Sundry Approval to workover Alpine Black Start Gas Storage Injector CD1-14(PTD#201-038). CD1-14 was drilled and completed in May of 2001 as Alpine's Black Start gas storage well. When fuel gas is unavailable due to plant outage,CD1-14's injected gas is produced to provide fuel for the electrical generation system at Alpine. This system is critical for Alpine camp operations, process safety in the production facility (heat, lights, instrument air, etc.), and is required to restart the production facility after any planned or unplanned shut down. Without another Black Start well available,CD1-14 is a critical well for continued operations at Alpine. In August of 2015 CD 1-14's inner annulus(IA)pressure was bled and increased to near pre-bleed pressure,indicating tubing by IA (TxIA) communication. After communication with the AOGCC, diagnostics were postponed to allow for Black Start production during the August 2015 Alpine turnaround. Following the turnaround,the well passed an IA mechanical integrity test(MIT-IA)and passed positive and negative pack-off tests(T-POT and T-PPPOT).These tests confirmed the integrity of the casing,production packer,and pack-offs. CPAI completed subsequent production and injection tests to verify the integrity of the well.The IA pressure stabilized at 1600 psi and never exceeded the"do not exceed"(DNE)pressure of 2400 psi.In December of 2015 CPAI received Administrative Approval for continued gas injection with known TxIA communication. In October of 2016 well CD1-14 was recommended for a workover to remediate the known TxIA communication.In January of 2017 wellhead diagnostics were performed, indicating the TxIA communication is from failed metal to metal and back-up polymer seals on the tubing hanger. Diagnostics indicate that the seals likely leak to gas in cold temperatures. A passing draw down test(DDT) and passing MIT-IA in March of 2017 confirm the integrity of the casing,tubing,and production packer. The objective of the workover is to pull and replace the 4-'/2" upper gas lift completion to remediate the TxIA communication in CD1-14 and return the well to full operational use. The existing tubing will be cut and pulled and a new gas-tight 4-'/2"completion will be installed, including a stacked packer and a gas-tight tubing hanger. This Sundry is intended to document the proposed work on CD1-14 to fix the known TxIA communication and to request a variance from 20 AAC 25.412 to allow the stacked packer to be set approximately 800'MD above the top of the open hole interval. If you have any questions or require further information, please call me at 265-1027 or email me at sara.heskin@cop.com. Sincerely, SW"'(4,A 11:-) Sara Heskin Associate Wells Engineer CPAI Drilling and Wells • • • ConocoPhillips CD1-14 Proposed Workover Pull & Replace Tubing, Stack Packer Original PTD: #201-038 General Well Information: Well Type: Alpine C Sand Gas Storage Injector(a.k.a. Black Start Well) MPSP: 3,765 psi from most recent SBHP w/gradient of 0.1 psi/ft to surface '7" 3,765 psi=(4,434 psi—(0.1 psi/ft*6,690'TVD)) Reservoir Pressure/TVD: 4,434 psi/6,690'TVD(12.8 ppg EMW) Using last recorded shut-in bottom-hole pressure on 12/17/15 Wellhead Type: FMC Gen II 5M BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure: 250/4,000 psi (3,500 psi high for Annular) Integrity Results: T-POT&T-PPOT—Passed March 2017. Upper and Lower M2M &SBMS Seals—Passed March 2017, but failed in January 2017. Suspect the tubing hanger seals leak to gas in low temperatures. MIT-IA to 2950 psi passed January 2017 Earliest Start Date: 4/6/2017 Production Engineer: Ilnur Mustafin Workover Engineer: Sara Heskin (907) 265-1027 sara.heskin@cop.com Current Well Status: CD1-14 is currently undergoing slick-line fishing operations to retrieve 2,100'of wire and a slickline toolstring that was lost downhole during pre-rig workover diagnostics.The well is currently operable for Black Start production upon rig-down of slick-line crews. If the fish cannot be retrieved prior to rig workover start date,the fish will be pushed downhole to allow the rig workover to be completed. Scope of Work: • Pull the 4-3z" Completion via a pre-rig tubing cut. • Run a new 4-1/2' Completion with a stacked packer, new tubing hanger, and gas-tight connections. Summary of Proposed RWO Procedure: Pre-Rig Work: 1. Retrieve fish or push fish to bottom. 2. Set tubing tail plug and catcher to isolate tubing from reservoir. 3. Punch tubing above plug to establish circulation and displace well to seawater. 4. Cut tubing at "13,339' MD. 5. Perform a C-MIT to 3000 psi to verify plug and packer as barriers. 6. Lock out SSSV. ✓ w ConocoPhillips CD1-14 Proposed Workover Pull & Replace Tubing, Stack Packer Original PTD: #201-038 Proposed Rig Workover Procedure: 1. MIRU Doyon 19. 2. Pull BPV. 3. Circulate KWF. Obtain SITP&SICP; if pressure is observed at surface, calculate new KWF and repeat circulation if necessary.Verify well is static prior to proceeding. 4. Set 'HP' BPV, ND tree, set Sealing HP Plug-Off tool to the BPV, NU BOPE, &test BOPE to 250/4,000 psig low/high. 5. Pull Sealing HP Plug-Off tool, pull `HP' BPV,screw in landing joint, BOLDS, & unseat tubing hanger. 6. P/U on tubing& pull tubing hanger to the rig floor. a. If tubing will not pull free, contingent on-rig e-line cut. 7. L/D 4-%2" upper completion to tubing cut at 13,339' MD 8. M/U &TIH with new 4-1A" upper completion as per design. 9. Circulate seawater in tubing and IA. 10. Space out and land tubing hanger. 11. Drop ball and rod to pressure up to set new production packer. 12. Pressure-test tubing to 3,500 psi & IA to 3,000 psi. Quickly bleed the tubing to shear the SOV. 13. Circulate diesel in tubing and IA. 14. Back-out landing joint& install 'HP' BPV. 15. ND BOPE, install Sealing HP Plug-Off tool to the BPV, NU tree, &pressure test tree to 250/5000 psi. Pull the Sealing HP Plug-Off tool. 16. RDMO Doyon 19. Proposed Post-Rig Work: 1. Pull BPV. 2. RU Slickline a. RIH to retrieve Ball and Rod & RHC Plug body. b. Run gas lift design &swap SOV for DV. c. Retrieve catcher. d. RDMO Slickline. 3. R/U IA to gas injection header. a. Utilize lift gas from injection header to evacuate diesel in IA and tubing. i. Due to the gas-storage nature of this well, the dry-gas reservoir is highly sensitive to foreign fluids. The tubing and IA will be evacuated to minimize the volume of diesel entering the formation to minimize formation damage. 4. RU Slickline a. Tubing tail plug. b. RDMO Slickline. 5. Reset well house(s) & re-attach flow line(s). 6. Turn well over to operations via Handover form. `v•. • FMC Gen II 11x 4-Y2"5M Tbg.Hanger • C D 1 -14 ConocoPhi lli psI I Alpine C-Sand Black Start Injector/Producer I I Proposed RWO I I 16" 62.5#H-40 WLD, 115' MD ✓ i 4-1/2" 12.6#L-80 HYD563 Tbg, 13339' MD 4-1/2" 12.6#L-80 IBTM Tbg, 13339'-13421' MD I __ 2300' MD,4-1/2" Camco BP6-I Nipple& DCIN-II Chemical Injection Nipple w/ ,"SS SSSV Control Line&3/8"Encapsulated Methanol Injection Line 9-5/8"40.0#L-80 BTC-MOD, 3587' MD —0-1 xxxx' MD, Camco 4?/2"x11/2" KBG-2 GLM SOV IA to Tbg.Pre-Installed,set as deep as possible -13250' MD, Baker 7"x 4'/2" Premier Packer ,`� f xxxx' MD, HES 3.875"X Nipple L I RHC Plug Body Installed 13339' MD-Pre-Rig Tubing Cut --I- - 13339' MD, Baker Non-Sealing Overshot d^-823 'Afok 13365' MD, Baker S-3 Permanent Packer 12/17/15 Last BHP Measurement: w/3.875"ID 4434 psi at 13420'MD/6690'TVD 1-110- 13409' MD,4-'/2"x 3.725" HES XN Nipple w/plug body installed pre-rig for reservoir isolation 13420' MD,4'/2"WLEG 7"26# L-80 BTCM, 14073' MD —NJ ®i �'.I, 6-5/8"Open Hole, 18,939' MD ► . Date: 22-March-2017 Drawn By: Sara Heskin t 03Se Regg, James B (DOA) From: ALP Ops Maint Supt <alp1167@conocophillips.com> Sent: Saturday, March 04, 2017 8:44 PM 3I ti7 To: Regg,James B (DOA) 1 -i 1 Cc: Alpine Environmental Subject: CD1-14 Gas release Jim,we had a gas release on well CD1-14 at Alpine during a routine slickline operation getting a static bottom hole pressure. As they were coming out of the hole the lower Otis union started to leak gas. the leak lasted two minutes and after an investigation of the cause (a failed 0-ring)the volume was calculated at 6.6 msfc.The time of the release was 19:30hrs on 3/3/17. I verbally reported it to the hotline number 907-659-2714 and was instructed to send you a note. Regards, Mike Lyden WNS Operations and Maintenance Superintendent ConocoPhillips Alaska Inc 907-670-4021 SCANNED MAY I 20 17: 20t - 03� 2C9'( 20 WELL LOG TRANSMITTAL# DATA LOGGED 2/1\/201 Co 1. K.BENDER To: Alaska Oil and Gas Conservation Comm. January 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JA S 12 6 2015 _ GCC RE: Multi Finger Caliper Log/Static Bottom Hole Pressure Survey: CI Run Date: 12/17/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1-14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20371-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / t� XHVZE Image P'roject Well History File Còver Page 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 1 - 0'0 g Well History File Identifier Page Count from Scanned File: I ~ ð (Count does include cover sheet) Page Count Matches Number in Scan ring Preparation: V YES A DateU'7/05 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided III" 11111111/1111I RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: NOTES: BY: G ~aria) Date: J '. >7/0S- Date: II 17/0S X 30= J cp.D + Date: Ií '7 / os- Project Proofing BY: ~ Maria ) Scanning Preparation BY: ~ if 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: o Rescan Needed III" 111111 11/1111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: . ~ Isl VVi 1111111111111111111 M1P /5/ ~ = TOTAL PAGES " ~d- (Count does not include cover 5 liVtt Q /51 . . 1111111111111111111 NO Isl ru J NO /5/ 111111111111111111 1111111111111111111 /5/ Quality Checked III "111111I11 IIIII 1 0/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO: Jim Regg ` (✓'ZI 113 P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-14 FROM: Jeff Turkington COLVILLE RIV UNIT CDI-14 Petroleum Inspector Src: Inspector Reviewed By: P.1.Suprvif-CA NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD1-14 API Well Number 50-103-20371-00-00 Inspector Name: Jeff Turkington Permit Number: 201-038-0 Inspection Date: 6/12/2013 Insp Num: mitJATl30614191942 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We❑ CDI-14 Type Inj G iITVD 6666 - IA 2045 2800 2780 2770" PTD 2010380 - Type Test SPT Test psi 1666 - OA 890 890 - 890 890 Interval 4YRTST - P/F P ' Tubing 4140 4140 4140 4140 - Notes: .9 bbl diesel to fill. SCANNED FEB 2 0 2014 Tuesday,June 18,2013 Page 1 of I ~ MEMORANDUM To: Jim Regg P.L Supervisor ~~ 7~ZZ~(~~ FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDl-14 COLVILLE RIV LTNIT CDl-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ . ~- Comm Well Name: COLVILLE RN LTNIT CD1-14 Insp Num: mitRCN090617212221 Rel Insp Num: API Well Number: 50-103-20371-00-00 Permit Number: 201-038-0 / Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ CD1-14 Type Inj. G ~'~ 6666 jA 1290 2960 ~ 2920 2920 P.T.D 2010380 TypeTest SPT TCSt ~Sl 2960 QA 800 800 800 800 ~ Interval 4YRTST P~' P / Tubing 3693 3693 3693 3693 Notes: ~,~~~ -~5-~ ~S5`~`e 1~~~ ~'~(. .,. `~ '~'~~,~. :E~t~F , €.~ ~~~j~;; Monday, June 22, 2009 Page 1 of 1 Message Page 1 of ~ ~_ Maunder, Thomas E (DOA) __ From: Wiess, JORDAN F [JORDAN.F.Wiess@conocophillips.com] Sent: Thursday, August 02, 2007 12:01 PM To: Roby, David S(DOA); Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dnve, ~~+~~As a result of receiving these interpretatio CPAI has initiated lean gas injection into CD1-02, ~ CD1-05 and CD1-21 (with CD1-06 and CD1;14 reviously on lean gas injection). CD1-11 is on long-term continuous miscible gas injection (no WAG) because it is twinned with CD1-05. When it reaches the end of its miscible gas EOR service, it will be converted to continuous lean gas injection as well. Also, after the facility shut down in August, CD2-06 and CD2-07 will start on lean gas WAG. Jordan ~ ~ ^ L~~.~ ;~:,..'~:~~~~~: iau ~, - ;. -----Origin al Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August 01, 2007 3:45 PM To: Wiess, JORDAN F; Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Jordan, One more thing, could you please tell us which three wells have been converted to lean gas injection, and email us when wells are converted in the future, so that we can put a note in the appropriate well files? Thanks again, Dave Roby Phone: 907-793-1232 email: dave,ro~(a~alaska.qoy From: Wiess, JORDAN F [mailto:)ORDAN.F.Wiess@conocophillips.com] Sent: Wednesday, August O1, 2007 8:18 AM To: Roby, David S(DOA); Uldrich, David 0 Cc: Maunder, Thomas E(DOA); Wilson, Chris; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order Dave R, Dave Uldrich is out of the office until mid/end of next week. I will ensure he provides you a prompt reply upon his return. Thnnks for your time last week. ~ ~~ , '4~~~~ ~cC.~ 8/17/2009 Message Jordan Page 2 of ~ ~-- -----Original Message----- From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Wednesday, August O1, 2007 8:15 AM To: Uldrich, David O Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, JORDAN F; Davies, Stephen F(DOA) Subject: RE: AOGCC Guidance on Alpine Area Injection Order David, I do have one request for you. During the meeting it was mentioned that normal laboratory testing to demonstrate miscibility wasn't working because of the way the samples were obtained and analyzed and that the MMP values that the lab determined were in error by several hundred psi. Could you please provide a short note, an email would be fine, to explain these problems and what you are doing to ensure miscibility? Thanks in advance, Dave Roby Phone: 907-793-1232 email: dave.robv alaska.qov From: Uldrich, David O [mailto:David.O.Uldrich@conocophillips.com] Sent: Tuesday, July 31, 2007 4:46 PM To: Roby, David S (DOA) Cc: Maunder, Thomas E(DOA); Wilson, Chris; Wiess, ]ORDAN F Subject: AOGCC Guidance on Alpine Area Injection Order Dave: I wanted to thank you and Tom very much for meeting with Jordan and myself last week. We appreciate your time and efforts to clarify the issues that we raised through the draft request for amendment of the Alpine area injection order. Having confirmation from you that the existing area injection order and State regulations permit post-MWAG lean gas injection, we are moving ahead with the plans we discussed with you. As we discussed with you, CPAI believes that the injection of lean gas in the post-MWAG injectors will enhance the recovery from the Alpine reservoir. As a result of the guidance that we received from you and Tom on behalf of AOGCC, CPAI has started lean gas injection into 3 wells that were previously used for miscible gas injection. These conversions, and several others we intend to implement later this summer, will help us manufacture gas that is miscible for the Alpine reservoir as well as the Fiord and Nanuq-Kuparuk reservoirs. In addition, we anticipate that the expanded lean gas injection will generate increased recovery through pressure maintenance and some reduced residual oil saturations. Thanks again for you help. David Uldrich Staff Reservoir Engineer Alpine Development Engineering ATO-1766 ConocoPhillips Alaska Inc. ~ (907) 265-6828 ~ David.O.Uldrich@conocophillips.com 8/17/2009 . ~1f iA\ 1fŒ (ill ~ iA\ ~iA\ ~ [[iA\ . AI,ASIiA. OIL AND GAS CONSBRVATION COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Crumrine, PE Alpine Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD 1-14 Sundry Number: 307-222 SCANNED JUL ~ 5 2007 Dear Mr. Crumrine: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. This well is already classified as an injection well. So long as the injection fluid is approved in the Area Injection Order no sundry authorization is necessary to change fluids. DATED thislg day of June, 2007 Enc!. ... <9 (){ -D3~ ~. . . RECEIVED Conoc~illips Alaska, Inc. JUN 2 7 2007 Post Office Box 100360 Anchorage, Alaska 99510-0360 Tim Crumrine, P.E. Alpine Production Engineer Phone (907) 265-6402 Fax: (907) 265-1515 .Alaska Oil & Gas Cons. Gammission AnchoraufI June 26, 2007 Alaska Oil and Gas Conservation Commission Attention: Tom Maunder 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Subject: Sundry Approval Request for Converting CD1-14 to Gas Injector Dear Mr. Maunder: ConocoPhillips Alaska, Inc., as Operator and on behalf of the working interest owners of the Colville River Unit submits this, Application for Sundry Approval to convert the CD1-14 currently on water injection to a gas injection well. This request for approval of gas injection is in accordance to the Alpine Area Injection Order. Converting the CD1-14 water injector will aid in managing miscible injectant blending, / which is the reason for our request. The well was originally a gas injector and has never had MI injection. If you have any questions or require additional information, please contact Dave Uldrich at ConocoPhillips Alaska, Inc., P. O. Box 100360, Anchorage, Alaska, 99510-0360, Telephone: (907) 265-6828. Additionally, Mr. Dave Roby has been involved with discussions surrounding this conversion and may be of assistance. Please see attached application. Yours very truly, (;:::- .._.._,,_.::::.::~--"'."'~ ···¿:Z Tim Crumrine, P.E. Alpine Production Engineer STATE OF ALASKA JU"I 2 72007 ALASKA OIL AND GAS CONSERVATION COMMISSION . I~ I APPLICATION FOR SUNDRY APPROVAL Alaska Oi 20 AAC 25.280 Operational Shutdown D Plug Perforations D Perforate New Pool D . . 1. Type of Request: D D 0· D D D Stimulate Abandon Suspend Perforate D D Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: " Spacing Exception Required? Yes D No 0 9. Property ~esignation: 10. KB Elevation (ft): ADL 25559/25560/372095 RKB 36' ' 12. PRESENT WELL CONDIT. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 18939' / 6814' /' Casing Length Pull Tubing 4. Current Well Class: Development Stratigraphic D D RECEIVED Gas Cons. C(}mmission Anchorage D D D Other D 5. Permit to Drill Number: 201-038 / 6. API Number: 50-103-20371-00 ' ame and Number: . Field/Pool(s): Colville River Field / Alpine Oil Pool / Size MD TVD CONDUCTOR 114' 16" SURFACE 3586' 9-5/8" PRODUCTION 14073' 7" OPEN HOLE 4866' 5-1/2" Perforation Depth MD (ft): (,.{ Packers and SSSV MD (ft) pkr= 13365' SSSV= 2298'; 2298' 14. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: Oil D Gas D WAG D GINJ 0 Packers and SSSV Type: pkr= BAKER S-3 PACKER, 4.5"X7" SSSV= NIP; SSSV 13. Attachments: Description Summary of Proposal Detailed Operations Program D 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is tr e and correct to the best of my knowledge. Printed Name Tim Crumri Contact: Title: Phone 265-6402 Commission Use Only tify Commission so that a representative may witness Plug Integrity D Mechanical Integrity Test D Location Clearance D Other: RBDMS BFL JUL 0 1 2007 Junk (measured): Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 13421 ' Service 0 Plugged D WINJ D Abandoned D WDSPL D Tim Crumrine Production Engineer Date c; /GG z./;<'.:>7 _~~"_'_==-._ =---,-~-----'-----"---'c·.~ =-==-", Approved by: Form 1 0-403 Revised 06/2006 APPROVED BY THE COMMISSION Date: ~ ~~~~ DU.EI!»8te 4P'"~~ ,-oyÞ'Þ7 . . ~ ConocoPhillips Alaska ,1, "J ,'~'. : ·7 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ ·i§¡ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 stANN EO fI.¡>R 1 \) 1.007 d.-D \_ 0 3~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" oa 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na· 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" oa 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" oa 6" oa 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" oa 4" oa 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" oa 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" oa 8" oa 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" oa 4" oa 1 3/8/2007 CD1-40 199-044 4" oa 4" oa 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" oa 8" oa 3.7 2/16/2007 CD1-44 200-055 10" na 10" oa 4.7 2/16/2007 CD1-45 199-101 4" na 4" oa 2 2/19/2007 CD1-46 204-024 36" oa 36" na 16.9 2/16/2007 Alpine Field March 31,2007 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _Inserts\Microfihn _ Marker.doc Re: Alpine CD 1-14 LPP request ) , !, Subject: Re: Alpine CD 1-14 LPP request From: James Regg <jim_regg@admin.state.ak.us> Date: Wed, 23 Mar 2005 10:04:03 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: Tom Maunder <tom_maunder@admin.state.ak.us> ¡¿OJ' oôr6 Your request to lower the low pressure pilot set point from 1800 psi to 1600 psi is approved for Alpine Well CDl-14. Jim Regg AOGCC Inspection Supervisor NSK Problem Well Supv wrote: Jim, ConocoPhillips requests approval to temporarily lower the low pressure pilot set point on Alpine MI injection well CDl-14 (PTD 201-038) from 1800 psi to 1600 psi until the well can be wagged to water injection (scheduled for -2nd week of April). Currently the reservoir pressure and corresponding injection pressure are too low to support the required LPP trip pressure of 1800 psi. The alternatives to lowering the set point are a man watch - in which we are manpower limited, or shutting in the well - in which reservoir impacts are suffered. Please let us know as soon as possible if this temporary change is acceptable MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNED MAR ~; 42.0D5 1 of 1 3/24/2005 8:07 AM Permit to Drill 2010380 MD 18939 REQUIRED INFORMATION TVD 6814 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Media f~ cr/ i ~. þY-'/ I c..-----' I~ I~ i~ ~- I~- iL I IL I !C ¡ ...----- iR i \.._...../ I Well Cores/Samples Information: Digital Fmt ...J...--' ~ ../ / v-- ~ ~ ~ L L ~ ~ Name ADDITIONAL INFORMATION II JIAV\~ DATA SUBMITTAL COMPLIANCE REPORT 6/2/2003 Well Name/No. COLVILLE RIV UNIT CD1-14 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20371-00-00 Completion Oat 5/11/2001 Completion Statu 1-01L Current Status WAGIN UIC Y Mud Log No Sample No Directional Survey ~ "-J 4. J (data taken from Logs Portion of Master Well Data Maint) Name Log Log Run Scale Media No Interval OH/ Dataset Start Stop CH Received Number Comments 3596 14003 Open 6/15/2001 /10136 3596-14003 3500 18939 Open 6/22/2001 vf0153 3500-18939 11983 13931 ch 6/1/2001 11983-13931 Color Print oh 5/23/2001 Directional Survey Paper Copy 3586 14003 OH 6/15/2001 3586-14003 BL, Sepia 3586 14003 OH 6/15/2001 3586-14003 BL, Sepia 3586 14003 OH 6/15/2001 3586-14003 BL, Sepia 3586 14003 OH 6/15/2001 3586-14003 BL, Sepia 3596 14003 oh 6/15/2001 -{0136 3596-14003 Digital Data 3586 18892 OH 6/22/2001 3586-18892 BL, Sepia 3586 18892 OH 6/22/2001 3586-18892 BL, Sepia 3500 18939 OH 6/22/2001 v10153 3500-18939, Digital Data 5/2/2001 Directional Survey Paper Copy '-' ..uarrWith Tractor 5 FINAL Directional Survey FINAL "-111 b V;tll<y'- t'~. ~g I LM6 Vi~ion. RES. ~ 2/5 FINAL t...F..J:a V·')H... ~ f ø i VISION RES 2/5 FINAL -.ME> VIS/DENlNEU fr!./ 2/5 FINAL ~ VISIDEN/NEU If> 1 2/5 FINAL 10136 FINAL TVD GR;:ì V / ( It rfA f' J-¿A FINAL MD GR f \¡,~,'h ~ fÞ$t 2/5 FINAL 10153 FINAL Directional Survey '--- Interval Start Stop Received Dataset Number Comments Sent Permit to Drill 2010380 MD 18939./ TVD Well Cored? Y / ~ Chips Received? ~ ¥ / N Analysis Y / N Rp.r.p.ivp.rl? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/2/2003 Well Name/No. COLVILLE RIV UNIT CD1-14 6814 "..-"" Completion Oat 5/11/2001 --- /{~ Operator CONOCOPHILLlPS ALASKA INC Completion Statu 1-01L Daily History Received? Formation Tops JplÞ.J Å C Ñh À6Ø ( API No. 50-103-20371-00-00 Current Status WAGIN Th/N ßyN Date: UIC Y ---- J J Wi~..<, /~ J ----- ,~ ~ ) r) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 314' FNL, 2797' FEL, Sec. 5, T11 N, R5E , UM At top of productive interval 10381 FNL, 19711 FEL, Sec. 3,T11N, R5E, UM At effective depth At total depth 1661 FNL, 4727' FEL, Sec. 11, T11 N, R5E , UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 1141 16" SURFACE 35861 9-5/8" PRODUCTION 140731 7" Stimulate _ Alter casing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 385908,5975813) (asp's 397284, 5974925) (asp's 399753,5970483) 18939 feet 6814 feet Plugs (measured) 18939 feet 6914 feet Junk (measured) Cemented 10 cu yds Portland Type 3 566 sx AS III & 237 sx Class G 235 sx Class G Perforation depth: measured Open hole completion from 140731 - 18939' true vertical Open hole completion Tubing (size, grade, and measured depth) 4-1/2",12.6#, L-80 Tbg @ 13421' MD. Packers & .5SSV (type & measured depth) BAKER S-3 PACKER, 4.5")(7" @ 13365' MD. CAMCO WRDP-2 @ 2298' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) NlA Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl N/A Prior to well operation Subsequent to operation Nt A 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _ Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. /' ¿ /P ,¿::J - . Ch~PNrso/ ~ h /~ Form 10-404 Rev 06115/88 · Title Alpine Engineer ORIGINAL Plugging _ Perforate _ Repair well _ Other _ X Conversion to WAG Injector 6. Datum elevation (DF or KB feet) RKB 36 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-14 9. Permit number I approval number 201-038 / 301-248 10. API number 50-103-20371 11. Field I Pool Alpine Oil Pool Measured Depth 1141 35861 140731 True vertical Depth 114' 23661 68551 E("¡~ ~:~ i ~\ lEi""""'D" , '\ ." '\JI,I....""~ ~II ", , 4.,' .¡J.;t'¡,'f.\" I ¡(~ 0 AlaSka 0,'1 " "', 0: tias CO"IS C " Al1cl1;r,;'g~ omrrllsslon Casing Pressure Tubing Pressure Suspended _ Service _ WAG Injector _XX Questions? Call Chris Pierson 265-6112 ~z-fAz Date Prepared by Sharon Allsup-Drake 263-4612 ~~ -ß SUBMIT IN DUPLICATE ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 314' FNL, 2797' FEL, Sec. 5, T11 N, R5E , UM At top of productive interval 1038' FNL, 1971' FEL, Sec. 3, T11 N, R5E, UM At effective depth At total depth 166' FNL, 4727' FEL, Sec. 11, T11 N, R5E , UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 114' 16" SURFACE 3586' 9-5/8" PRODUCTION 14073' 7" Perforation depth: Stimulate Alter casing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 385908, 5975813) (asp's 397284, 5974925) (asp's 399753, 5970483) 18939 feet 6814 feet Plugs (measured) 18939 feet 6914 feet Junk (measured) Cemented 10 cu yds Portland Type 3 566 sx AS III & 237 sx Class G 235 sx Class G measured Open hole completion from 14073' - 18939' true vertical Open hole completion Tubing (size, grade, and measured depth) 4-1/2",12.6#, L-80 Tbg @ 13421' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER, 4.5"X7" @ 13365' MD. CAMCO WRDP-2 @ 2298' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl N/A Prior to well operation Subsequent to operation N/A 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /' ./ ¿;? ~- Title Alpine Engineer ChriSPierso~ h /~~ Form 10-404 Rev 06/15/88 · Plugging _ Perforate Repair well _ Other _ X Conversion to WAG Injector 6. Datum elevation (OF or KB feet) RKB 36 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-14 9. Permit number / approval number 201-038/301-248 10. API number 50-103-20371 11. Field / Pool Alpine Oil Pool Measured Depth 114' 3586' 14073' True vertical Depth 114' 2366' 6855' \1 o¡,)) Î/X7 0"7/ 10 ..3 ,. 2ð:J/ Casing Pressure Tubing Pressure Suspended _ Service _ WAG Injector _XX Questions? Call Chris Pierson 265-6112 ~Z~~~. Date Prepared by Sharon Allsup-Drake 263-4612 ORIGINAL ~BDMSBFL J4N 3 I 2002 ~ SUBMIT IN DUPLICATE <PHI~'\ ph.lups Alaska, Inc. ) ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Erwin Phone (907) 265-1478 Fax: (907) 265-6224 October 3, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations CDI-14 (201-038/301-248) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent conversion of the Alpine well CDI-14 from producer to gas injector. If there are any questions, please contact me at 265-1478. Sincerely, /~L M. Erwin Alpine Production Engineer Phillips Alaska, Inc. ME/skad RECEIVED OCT 0 4 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL r ~ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 314' FNL, 2797' FEL, Sec. 5, T11 N, R5E , UM At top of productive interval 1038' FNL, 1971' FEL, Sec. 3, T11 N, R5E, UM At effective depth At total depth 166' FNL, 4727' FEL, Sec. 11, T11 N, R5E , UM 12. Present well condition summary Total depth: measured true vertical Stimulate Alter casing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Servlce__X (asp's 385908,5975813) (asp's 397284,5974925) (asp's 399753, 5970483) 18939 feet 6814 feet Plugs (measured) Plugging _ Perforate Repair well_ Other _Conversion to Gas Injector 6. Datum elevation (OF or KB feet) RKB 36 feet 7. Unit or Property name Colville River Unit 8. Well number CD1-14 9. Permit number / approval number 201-038/301-248 10. API number 50-103-20371 11. Field / Pool Alpine Oil Pool Effective depth: measured 18939 feet Junk (measured) true vertical 6914 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 114' 16" 10 cu yds Portland Type 3 114' 114' SURFACE 3586' 9-5/8" 566 sx AS III & 237 sx Class G 3586' 2366' PRODUCTION 14073' 7" 235 sx Class G 14073' 6855' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-BO Tbg @ 13421' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER, 4.5"X7" @ 13365' MD. CAMCO BAL-O LANDING NIPPLE SET 5/18/01 @ 2298' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 3912 8999 "0" Prior to well op, 9/3/01 N/A Subsequent to operation N/A 18214 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil Gas _X 17. I h~Y certify that the foregoing i: true and correct to the best of my knowledge. Signed ~e«Q ~ Title Staff Engineer Mike Erwin Form 10-404 Rev 06/15/88 · OR\G\NAl RECEIVED OCT U4Z001 Alaska Oil & Gas Cons. Commission Anchorage Casing Pressure 100 Tubing Pressure 432 2485 11011 250 Suspended _ Service Questions? Call Mike Erwin 265-1478 Date 10/3/0 Prepared by Sharon A/lsu¡rDrake 263-4612 ~ --~ SUBMIT IN DUPLICATE ) ) F PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Erwin Phone (907) 265-1478 Fax: (907) 265-6224 RECEIVED AUG 1 7 2001 Alaska Oil & Gas Cons. Commission Anchorage August 15, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 w. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: CDl-14 Application for Sundry Approval (APD 201-038) Dear Ms. Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to convert the Alpine CDl-14 well from a producer to an injector. If you have any questions regarding this matter, please contact me at 265-1478. Jjncerely, /!1(~ò-L M. ~rWln Alpine Production Engineer ME/skad ) ) \ jtA!(.¡o) ~ ~\lV ./J. c:..¡ 'S" eþy~0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. o. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 314' FNL, 2797' FEL, Sec. 5, T11 N, R5E , UM At top of productive interval 1038' FNL, 1971' FEL, Sec. 3, T11 N, R5E, UM At effective depth At total depth 166' FNL, 4727' FEL, Sec. 11, T11 N, R5E , UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 114' 1611 SURFACE 3586' 9-5/811 PRODUCTION 14073' 711 Perforation depth: measured None true vertical None Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 385908,5975813) (asp's 397284, 5974925) (asp's 399753,5970483) 1 8939 feet 6814 feet 18939 feet 6914 feet Plugs (measured) Junk (measured) Cemented 10 cu yds Portland Type 3 566 sx AS III & 237 sx Class G 235 sx Class G Tubing (size, grade, and measured depth 4-1/2",12.6#, L-80 Tbg @ 13421' MD. Packers & SSSV (type & measured depth) BAKER S-3 PACKER, 4.5"X7" @ 13365' MD. Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) RKB 36 feet 7. Unit or Property name Other _X Conversion Colville River Unit 8. Well number CD1-14 9. Permit number / approval number 201-038 10. API number 50-103-20371 11. Field / Pool Alpine Oil Pool Measured Depth 114' 3586' 14073' True vertical Depth 114' 2366' 6855' RECEIVED AUG 1 7 2001 Alaska Oil & Gas Cons. Commission Anchorage CAMCO BAL-O LANDING NIPPLE SET 5/18/01 @ 2298' MD. 13. Attachments Description summary of proposalJ Detailed operations program _ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: September 1, 2001 16. If proposal was verbally approved Oil _X Gas Suspended _ Name of approver Date approved Service 17. I hereby certify that the foregoing is rue and correct to the best of my knowledge. Questions? Call Mike Erwin 265-1478 /11'v1 b /) " "- Signed r ~ ~Qt,Lk: ~ Title: Alpine Production Engineer Date ßJ 15 / 0 J Mike érwitt Prepared by Sharon Allsup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no, ~/)/.. f'/í Á.r7 Plug integrity __ BOP Test _ Location clearance ~ t7','""1 ð Mechanical Integrity Test t Subsequent fonn required 1 0- ~ (\ \ Approved by order of the Commission ,Original Signed BV Cammy Oechsli Form 10-403 Rev 06/15/88 · ORIGIN A.! Commissioner Date q)¿; /ó I SUBMIT IN TRIPLICATE ) ) MECHANICAL INTEGRITY REPORT' '.. . 'dO \-OS ~ ') ... ~?UD D.~.:E: l'd<-=''' ~bO \ OPER Ex FIELD ?"?<../G - ~ \~\~ :.~G RELEJ._S'::: .5/\\ _ ";:)()c \ ~""ELL NUMBER c.\) \ - \ L-\ \'q",~ ~ ~ ~ ~u~~ ~~~.~ ~ Ç'\ \\ ct-"t> 'O~\.'Ð" ~<k. \ \ 7~ ~LL DATA TD: \<6~ ~~.HD.. <0 <6\~ TVD; :?:BTD: Sû'f'l\~ MD '5Þ()'''''~ TVD Casir:.g: \ Shoe: \ ';()\3HD <O<is-SS- TVD; DV: ~ Þ. MD \-..Jb... ·Tvu ~:":1e~ : ~~ Shoe: ~ b. ill) ~ ~ TVI); :OP: ~ b.;... HD ~~ :VD :- U 0 i:: g: l..\' Ië>'\ Packer \?> ~ ~Sf HD TVD i Set ê.. t: \ S \....\;:}. \ « ::-:'ole Size <Õ'lø" ana <O\/f!; Perfs O~ctt\ to \-i-f\\«' .... \ '--\0'\ ~ - \~<; ~c.;' .,v... ~ ,--~S 5 ' - I. C-.\ Li \ '\. d.~' <. ""~~<P~ \ \ ~CHÞ...NIC;'.L INTEGRITY - PART ¡ 1 vo \J:j) 0\, .'IoIV Annulus Press Test: ~p 15 min 3 0 min COITiIIlents: /' :-ŒCHjÜ~ICAL INTEGRITY - PART /2 Cement Volumes:" þ...mt. Liner ~ ~ Csg d~ ~~ DV \J~ Cwt ~ol to cover peris ~~ 0'('. ~'Zo~~ \o<:..~~~\.b~~'o~t".~ \~L\~C.. ~~~()..\ 'l'heoret.ical Toe ~()C ~~'""- 'n~~~, ~ \~~)(\. Rt'"~ ~~~ $)~-\. ,,((.."""«.~~~ ~~(t'~ ~'~~'û ~q. \\ Q.~~'-J<C ~~<t ~~c~-\-~~ ~\t--' f'\b C~ent Bond Log j;~or No) ; In AOGCC File ''1~'> ',\~_~~~\~,\~(è ~ \~Qt .' . CBL !:.valuat~on, ::.one ë.DOve perfs ({.~c:.It'\\~~m~'\~ \~\~~ ~'" \~~''') ~ ~ \ ~~\S - \ "3'-\~, I:',,~~~~ \~~'\S- \~~S() "'~~ \r-.~Ç;"t"\\"'~t'\,,""i>C"(.~~\~~~ \,\..)\;;~~~""'~ fY\.\Jð l..ç\$,\~ ~,~~~«:<~~~~. ~~~c:::. \'t~~~\~~~~~~'\~~\~~~~, Production Log: Type ¡Evaluation ',. CONC;LUSIONS: ? ar t: if 1 : .- ? arc: : 2: M::L'"\..", ,\,,~, <:"CL- ~~ " .... A-<t~"'("S-{) \ - ~ ~ /. Çb.<... \..<t.... \--0..,,;> '0,<: ~ ~ 'i>ct-\- ~ \- 0. ~<:c.\>-T~ '-Ù -\...... ....~ ~~ -\- \ <;'1:) \ 0.\ \1:) ~ ~ro-.) \ tJ~c) ~M ö. 't>c ~Q. ~ \ ~ 0' ?~dat~ \~.~ ,-\\Ç;} <:l\Ð'O~ ~~"O~ ~\~\ ~Q:.. 'Ç)\~,t.~~ \ ~ ~~Cè.~~ 'vj \<è, ~13"~' ) ~s') PHilliPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY ) Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 July 3, 2001 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CDl-14 (201-038 / 301-044) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well CDl-14. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, ~ L, {)(.{ RECE\VED G. C. Alvord Alpine Drilling Team Leader PAl Drilling JUL 0 52001 Alaska Oil & Ga$ Cons. Commission Anchorage GCA/skad ORIGINAL ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 . Status of well Classification of Service Well Oil 0 Gas 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface o Suspended o Abandoned 0 Service 0 ~_,7. Permit Number Q.~. . ".: L' 201-038/301-044 , .. .j 8. API Number f. ".,~"";,,c.~"."" '.,j. 50-103-20371-00/50-103-20371-70 · ", \!!f~.,)J ~ J:"'..,..",.,'_.,..."..._..~'-'?~" ,,, \.¡ ·.:..·.11 9. Unit or Lease Name ¡I DÜJ\¡Ii\C; l(;~\¡ ~ Colville River Unit ~ S/9';)~ðl f 10. Well Number ~...1-¥-1. ..~-;.f.!f~I~··- t. CD1-14/ CD1-14PB1 1: -~ . ED ¡ W,,, <:::- ~ 11. Field and Pool :g,:~;"-;;,,._.:J Colville River Field Alpine Oil Pool 315' FNL, 2482' FWL, Sec. 5, T11N, R5E, UM (ASP: 385908,5975813) At Top Producing Interval 1038' FNL, 1971' FEL, Sec. 3, T11 N, R5E, UM (ASP: 397284,5974925) At Total Depth 170' FNL, 551' FWL, Sec. 11, T11N, R5E, UM (ASP: 399753, 5970483) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 36 feet ADL 25559/25560/372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. February 26, 2001 May 7,2001 May 11,2001 17. Total Depth (MD + TV D) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 18939' MO/6814'TVD 18939'MD/6814'TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res/Dens/Neutron in pilot hole / GR/Res in horizontal 23. 15. Water Depth, if offshore N/ A feet MSL 20. Depth where SSSV set 2298' 16. No. of Completions 1 21. Thickness of Permafrost 1747' feet MD CASING SIZE WT. PER FT. GRADE 16" 62.5# H-40 9.625" 40# L-80 7" 26# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 3586' Surface 14073' HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 10 cu yds Portland Type 3 566 sx AS III & 237 sx Class G 235 sx Class G 12.25" 8.5" CD1-14 PB1 cement plug dressed off to 12140' to start CD1-14 well 24. Perforations open to Production (MD + TVD of Top and Bottom and Interval, size and number) 4.5" TUBING RECORD DEPTH SET (MD) 13421' PACKER SET (MD) 13365' 25. SIZE Open Hole completion 6.125" OH from 14073' - 18939' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14003' - 12800' Plug #1: 92 bbls 15.8 ppg Class G 12800' - 12120' Plug #2: 125 bbls 17 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 25, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/2/2001 11.5 hrs Test Period> 3445 3238 0 99 1371 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (COlT) press. 290 psi not available 24-Hour Rate> 7152 6722 0 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEiVED N/A JUL 0 5 2001 Alaska all & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE OR\G\NAL Submit in duplicate 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Alpine 0 13792' 6824' Alpine 13849' 6837' N/A RECEIVED JUL lJ 5 70n1 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Alaska Oil & Gas Cons. Commission AnrhOfago Questions? Call Scott Reynolds 265-6253 SI9ned_# '- CM. G. C. Alvord Title Alpine DrillinQ Team Leader Date 7(3!lJf 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 OR1G1NAL Rpt Date 02/25/01 12:00 AM 02/26/01 12:00 AM 02/27101 12:00 AM 02/28/01 12:00 AM 03/01/01 12:00 AM 03/02/01 12:00 AM ) Operations Summary CD1-14 ) Comments PJSM. Prepare rig for move, move out motorlpit complex, pipe sheds, center rig on subbase complex and move sub off of well. Part BOP stack into individual components for annual inspection. Move subbase to CD1-14 Move Subbase over hole, land Divertor and center rig. Skid rig over hole, spot pitslmotors complex. NU Divertor, riser and flowline, take on mud in pits. Accepted rig @ 0530 hours. MU BHA #1. Held Pre-Spud meeting with Rig Team, performed Divertor test. John Crisp (AOGCC) waived witnessing test. Fill hole, test mud lines to 2500 psi and check system for leaks. Spud well, drill from 114' to 177'. ART =0.2 Change out UBHO su, leaking around alignment lug set screws. Drill from 177' to 482', surveying with Gyro. ART =1.0 AST =1.4 POH to motor, set AKO down to 1.4 degrees. Drill from 482' to 614". ART =0 AST =1.4 Drill from 614' to 3240'. ART=8.4 AST=7.0 Drill 12 1/4" hole fl 3240' tro 3596' Circ & condition mud Wiper trip fl 3596' to 1450' - hole in good condition Circ hole clean - monitor well POOH to run csg - worked through some tight spots fl 1134' to 750' UD BHA Clear rig floor of BHA tools Rig up to run 9 5/8" csg Held PJSM - Ran Float shoe - 2 jts. 9 5/8" 40# L-80 MBTC csg - float collar - 24 jts 9 5/8" 40# L-80 MBTC csg Continue running 9 5/8" 40# L-80 csg - ran 86 jts. total landed on mandrel wI float shoe @ 3586' float collar @ 3502' Circ and condition for cmt job Rig down fill up tool - Rig up cmt head Held PJSM Cement 9 5/8" csg - pumped 40 bbls. Vis water wlnut plug - test lines to 2500 psi - drop btm plug - pump 50 bbls Arco spacer @ 10.5 ppg - mix and pumped 448 bbls 10.7 ppg lead slurry and 49.5 bbls 15.8 ppg tail slurry Rig down cmt head - landing jt. - wash out riser and 20" diverter Lay down 32 stds. 5" DP - 9 stds. HWDP - 40 stds 3 1/2" DP from derrick Nipple down diverter, riser, flow line Install FMC Unihead Finish installing FMC Unihead - test seals to 1000 psi Rig up to run 4 1/2" kill string - Held PJSM - Ran 62 jts 4 1/2" 12.6 # L-80 IBTM tbg - landed in wellhead wI tbg hanger- tail @ 2738' Nipple up Tree - Test tbg hanger seals & tree to 5000 psi Rig up to test 9 5/8" csg - pressure up to 2500 psi - observed leak in cmt line - bleed off pressure Rig up steel line to tbg to test csg Test 9 5/8" csg to 2500 psi for 30 mins. Pump 40 bbls vis brine - test line to 2000 psi - Pump 156.5 bbls diesel for freeze protection Rig down lines - Set BPV - Secure well Clean pits and inject returned fluids from well - freeze protect CD1-31 - Suspend well - Release rig @ 1800 hrs 3/2/2001 ) Operations Summary CD1-14 ) 03/31/01 12:00 AM Move rig f/ Nigliq to CD1- 14 04/01/01 12:00 AM Finish moving f/ Nigliq #1 to CD1-14 - spot & shim sub base - jack rig floor over well - move pits & motors into position Rigging up railings - landings - service lines Accept Rig @ 14:30 hrs. - N/U down tree - N/U BOPE flow line - turn buckles - choke & flare lines - mud line - take on mud in pits P/U 4 1/2" landing jt. w/ xo & TIW valve Pull BPV - M/U landing jt. to tbg. hanger Install double annulus valves & rig up hard line to catch tank for displacing diesel from well R/U tong and equip. to pull 4 1/2" kill string - finish taking on mud & mix Hi - Vis pill - Prep to displace freeze protect diesel form well 04/02/01 12:00 AM PJSM - Displace freeze protect diesel w/ 9.6 ppg mud f/ 2738' - observe well - pump dry job Blow down allllines - rig down circ equip Back out lock down screws - Pull tbg hanger to rig floor - UD tbg hanger Pull & UD 4 1/2" kill string - 62 jts.- Rig down tongs Install test plug - rig up test equip - thaw out kill & choke lines Fill stack - test BOPE - hydril to 250 psi low & 3500 psi high - pipe rams - blind rams- kill & choke line valves - choke manifold valves - inside BOP - floor safety valve - dart valve to 250 psi low & 5000 psi high Pick up and std back 5" drill pipe 04/03/01 12:00 AM Continue Picking up 5" DP & std back in derrick (114 stds) C/O saver sub in top drive M/U BHA #3 - orient motor & MWD - Install RA source in neutron sub - P/U Flex DP & HWDP - Pulse test MWD @ 600' - RIH to 3399' (P/U 81 more jts. 5" DP) Cut & slip 60' drill line Wash f/ 3399' to 3442' - Drill stringers f/ 3470' to 3495' Circ for casing test Pressure test 9 5/8" csg to 2500 psi for 30 mins. Clean out shoe track - FC@ 3502' - Drill shoe @ 3586' Circ for F.I.T. Perform F.I.T. to 16.1 ppg EMW w/ 9.6 ppg mud Pump sweep & change well over to 9.6 ppg LSND mud Drill 81/2" hole f/ 3616' to 3883' - 2497 TVD - ADT- 1.5 04/04/01 12:00 AM Drill 8 1/2"hole f/ 3883' to 4950' - xxxx' TVD - ART-7.4 AST-.6 Decreasing pump pressure & flow rate through MDW decreasing - Pump sweep Observe well - POOH checking for wash out Pull HWDP - found wash out in body of Jars - change out jars - remove RA source f/ MWD - pull out & check motor & bit - bit balled up - clean bit RIH w/ bit - motor - MWD - install RA source -RIH to 834' - pulse test MWD RIH f/ 834' to 2735' - fill pipe - RIH to 4836' - Break circ - wash to 4931' Circ & condition mud - mud aired up Drill 8 1/2" hole f/ 4950' to 5303' - 3126' TVD - ART - 1.9 - 04/05/01 12:00 AM Drill 8 1/2" hole f/ 5003' to 7587' - 4123' TVD Pump sweep & circ for wiper trip Monitor well - wiper trip f/ 7587' to 4726' - hole in good condition - monitor well RIH f/ 4726' to 6700' - fill pipe - RIH to 7587' - break circ 04/06/01 12:00 AM Drill 8 1/2" hole f/ 7587' to 10,060' - TVD 5243 - ART 13.5 - AST 1.8 Circulate sweep. Prep for wiper trip. 04/07/01 12:00 AM Continue circulation/condition hole. ) Operations Summary CD1-14 ') Blow down top drive and observe well. Wiper trip to 8600'. Improper hole fill last five stands. Observe well. Pump out 8600' - 8100'. Hole fill good. Observe well. Continue wiper trip to 7300'. Hole fill OK. RIH to 10060'. Establish circulation and drill from 10060' - 11,776'. 5966 TVD - ART 9.3 - AST 1.8. 04/08/01 12:00 AM Drill from 11,776 - 12,440. TVD 5,245, ADT - 4.5, ART - 3.4, AST - 1.1. Circulate and condition hole. Pump weighted high-vis sweep. Observe well and blow down top drive. Wiper trip to 9,670. Hole looked good with proper fill. RIH from 9,670 to 11,573. Filled pipe at 11 ,573. RIH from 11,573 to 12,350. Establish circulation and safety ream to 12,440. Pump sweep and drill from 12,440 to 13,201. TVD 6,596, ART - 5.2, AST - 0.7, ADT - 5.9. 04/09/01 12:00 AM Drill from 13,201 to 13,867. Hole taking fluid. Mix LCM. Circulate. Spot LCM pill 20 PPB. Full returns. Observe well - static. Drill from 13,867 - 14,003 (6956 TVD). ART -7.9 hrs. Hole taking fluid. Est 70 - 100 BPH. Spot LCM pill on btm @ 5 BPM (20 PPB). Monitor well on trip tank for 15 min - no losses. POOH to 11,142. Check flow and pump dry job. POOH to 300' Std back HWDP & Flex DC - Pull RA source f/MWD. Prep to UD BHA. * note lost appox. 8 bbls/hr. on trip out 04/10/01 12:00 AM Continue to lay down BHA. P/U 3-1/2 DP from shed and RIH with cement assembly to 2,700'. Cut and slip drill line. Lubricate and service top drive. Continue RIH. Obersever well at shoe. Fill every 3,000 to 14,003'. Establish circulation (2 BPM @ 510 psi). Monitor loss rate @ 150 BPH. PJSM - w/ Mule shoe @ 14,003' - set plug #1 w/40 bbls Class G @ 15.8 ppg - Displace to equalize - Calc. top @ 13,429' - CIP @ 12:45 hrs. UD cement head. POOH to 12,100'. Circulate pipe volume at 6 BPM. RIH to 13400'. Washdown to 13500'. Circulate BU @ 6 BPM. PJSM- w/ mule shoe @ 13500' - set plug #2 w/ 29 bbls class G @ 17 ppg - Displace to equalize - Calc top @ 13088' - CIP @ 19:00 hrs. Rig down cement head and POOH to 12100'. Circulate BU. POOH to 8204'. 04/11/01 12:00 AM POH, monitor well @ shoe, static, POH with cement assy. Pull wear bushing and install test plug. Test BOPE, choke manifold and surface safety valves 250/5000 psi, Annular Preventor 250/3500 psi. Pull test plug and install wear bushing, John Spaulding (AOGCC) waived witnessing tests. MU BHA #3, shallow test tools. RIH to 3500'. Slip and cut drilling line. RIH, fill pipe every 2000' to 12450'. Wash and ream, clean out cement stringers from 12450' to 12983', intermittent packing off, 25-50k overpull. Pumped high vis sweep. Clean out cement from 12983' to 13050', continuing to have packing off and over pull difficulty. ) Operations Summary CD1-14 ) 04/12/01 12:00 AM Clean out cement from 13050' to 13103', hole packing off, stalling TD @ 24500 ft/lbs. Worked pipe up hole, regained full circ, set back 1 stand. Pumped wt. high vis sweep and circ hole clean, working pipe 90' @ 100 rpm. Clean out cement from 13103' to 13158', intermittent packing off, TD stalling. Worked pipe up to 13067', set back 1 stand. Pumped low vis sweep with 15 ppg nutplug, reciprocated pipe @ 100 rpm, intermittent packing off continued. Backream out to 12685', 330-350k up, intermittent packing off. continued to backream to 12496', 315-340k up, slight packing off. Reciprocated pipe @ 100 rpm from 12496' to 12401' with full pump rate, pumped wt. high vis sweep and circ hole clean. Pumped out 2 stands, 300-305k up, and pulled last stand to 12100', no problems. RIH to 13158' precautionary ream last stand, no problems. Reciprocated pipe 90' @ 110 rpm Pumped wt.sweep and circ hole clean - no problems. Cleaned out cement from 13158' to 13175' - orientated motor 90 rohs and drilled to 13191' hole packed off. Work stuck pipe - appying and releasing torque for 1 st hour - unable to circ. Tripped up jar several times 375-400k pulling to 475k. Continued to work stuck pipe applying and releasing torque - regained circ. and worked pipe free. Reciprocate pipe @ 100 rpm. pumped wt.sweep and circ hole clean. Pump out to 12755' POH - overpull graduallyincreased 30k from 12000' to 11820' - slight swabbing on last stand. RIH to 12010' pump wt. high vis sweep and circ. hole clean. 04/13/01 12:00 AM Monitor well, static, POH. Wiped through tight spots from 10403' - 10022', 7863' - 7730',4793' - 4705', 20-40k over. CBU @ 4793', monitor well, POH to BHA, monitored well @ shoe 10 min, static. Stand back BHA, LD MWD and Motor, clear tools and clean rig floor. PJSM. RIH with 10 stands of 3-1/2" DP tail below 5" drill pipe to 13191', broke circ every 2000', precautionary circ last stand to bottom. Circ and cond mud @ 14 bpm -2420 psi, PJSM with Dowell. RU and test cement lines to 3000 psi, plugged back OH from 13191' to 12576' with 252 sxs of 15.8 ppg G cement, CIP @ 2130 hours. Pulled up to 12576', CBU, dumped 40 bbls of (lightly) cement contaminated mud. RU and test cement lines to 3000 psi, plugged back OH with 166 sx of 17.0 ppg G cement, displacing to equalization at midnight. 04/14/01 12:00 AM Displace cement to equalization, CIP @ 0010 hours, ETOC @ 12225'. Pulled up to 12230 and CBU, dumped 30 bbls of (lightly) cement contaminated mud. Monitor well, static, POH. MU BHA #6 and shallow test tools. RIH to shoe. Slip and cut drilling line, service Top Drive and blocks. RIH to 11675', slack off wt. decreased 20k. Wash down from 11625' to 11742', pump high vis sweep, reciprocate pipe @ 110 rpm and circ hole clean. Wash and ream from 11742' to 12410', Stalled Top Drive several times from 12200' to 12410', work pipe free with 25-35k over. Cleaned out soft cement from 12410' to 12485' stalled Top Drive several times worked pipe free with 25-40k over. 04/15/01 12:00 AM Clean out very soft cement from 12485' to 12680'. Continued to have difficulty with torque stalling Top Drive, working pipe free with 25-35k over, several times in areas previously reamed free and clean. ) Operations Summary CD1-14 ) Pump out to 12205', backreamed tight spots. Pump wt. high vis sweep and circ hole clean. Pump out to 11730' and POH to 9830', pump dry job. POH to BHA, worked pipe through tight spot from 7769' - 7740', 30-50k over, monitored well @ shoe. Stand abck BHA, LD MWD and Motor. RIH with 10 stands of 3-1/2" drill pipe below 5" drill pipe to 12600', establish circ every 2000'. Wash down to 12680', wash out soft cement from 12680', unable to wash below 12803' . Pump wt. high vis sweep and cond mud. 04/16/01 12:00 AM Circ and cond mud, PJSM with Dowell. RU and test cement lines to 3000 psi, plug back open hole from 12800' with 340 sxs of 17.0 ppg G cement, displaced to equalization. CIP @ 0250 hours, ETOC based on 60% washout 12260'. Pulled to 12293' and CBU, dumped 70 bbls of cement contaminated. Circ and cond mud, WOC. Wash down with low pump to 12426', CBU, no cement in returns. Wash down and tag cement @ 12456', CBU, PJSM with Dowell. RU and test cement lines to 3000 psi. Plug back back open hole from 12454' with 360 sxs of 17.0 ppg G cement. Displaced to equalization CIP @ 1310 hours, ETOC based on 60% washout 11886'. Pulled to 12007'. CBU, dumped 100 bbls of cement contaminated mud. Circ and cond mud to lower fluid loss. Monitor well, static, pump dry job. POH, monitor well at shoe, continue to POH. Pull wear bushing and install test plug. Test BOPE. 04/17/01 12:00 AM Test BOPE, choke and surface safety valves 250/5000 psi, Annular preventor 250/3500 psi. Jeff jones (aogcc) waived witnessing test. Install wear bushing. MU BHA #3, shallow test tools. RIH to shoe. Slip and cut drilling line, service Top drive and Blocks. RIH to 12700, fill pipe every 2000', no problems. Precautionary wash and ream from 12700' tagged cement @ 12120'. Clean out cement from 12120' to 12140'. Pumped wt. high vis sweep and circ hole clean. Sidetrack well and drill from 12140' to 12517'. ART =3.65 AST =3.2 04/18/0112:00 AM Drill from 12517' to 13262'. ART=8.23 AST=3.02 Pump wt.high vis sweep and circ hole clean, monitor well, static. Wiped hole to 11775', several tight spots from 12526' t012450' 25-35K over and worked pipe past tight spot @ 11900' with 30-50k over. Monitor well, static, RIH to 13170', no problems. Precautionary wash amd ream from 13170' t013262', pump high vis sweep. Drill from 13262' to 13440'. ART =1.09 AST =1.97 04/19/01 12:00 AM Drill from 13440' to 13643', difficult to slide. ART =2.1 AST =1.4 Pump wt. high vis sweep, circ and cond mud. Drill from 13643' to 13709'. ART =0.74 AST =1.14 Drill from 13709' to 14037'. ART =0 AST = 7.12 04/20/01 12:00 AM Drill from 14037' to 14090'. ART =0 AST =1.02 Pumped wt. high vis sweep and condition mud for wiper trip. Monitor well, static, Pump out from 14090' to 13643', wipe hole to 10783', max over 45k from 11580' to 11500'. Monitor well, static, RIH slowly to 14000', no problems running in ) Operations Summary CD1-14 ) Stage pumps up and precautionary wash and ream to 14090'. Pump Wt. high visl low visl wt.high vis sweeps and circ hole clean. Monitor well, static, pump out to 13643'. POH 10226', 15-30k drag. Work through tight spots from 10226' to 9841', 30-60k over. Pump out from 9841' to 9461', backreamed through numerous tight spots, no differential pressure observed on bit. 04/21/01 12:00 AM Pump out, backream tight spots from 9461' to 9366'. Attempted to back Top Drive off of stand, lost reverse capability. Troubleshoot Top Drive, work pipe and circ on hole, rotate pipe when Top Drive hot. Abort repair attemps, PJSM on switching DC power cables at SCR house to provide forward/reverse capabilities Pulled 2 stands to 9366', pump out from pulling 35-50k over, backream tight spots 9366' to 9175', pump out to 8700', 20-35k over. POH f 1 8700' t 1 8029', pump out f 1 8029' t 1 7458', numerous tight spots 30-45k over. POH 7458' - 7132'. Pump out f17132' t/ 660 Reciprocate pipe w/100 rpm, pump wt.high vis sweep and circ hole clean, observed very slight increase in cuttings when sweep returned across shakers. POH from 6031' to 5554'. 04/22/01 12:00 AM POH t/5487', Pump out from 5487' to 5273'. Backream f/5273' t/ 5178', pump out f/5178' t/4987', backream f/4987', stuck pipe @ 4727'. Apply torque and jar down on pipe, free pipe. Pump out to shoe, backreamed several tight spots. Troubleshoot Top Drive, circ hole. POH from shoe. Standback HWDP, LD BHA, no balling on BHA. MU BHA #8. RIH to shoe. Slip and cut drilling line - service Top Drive. Electrician serviced Top Drive motor. RIH to 6446' - no problems. Pumped wt.high vis sweep and circ clean @ 14 bpm - 130 rpm - very slight increase returns at shaker from sweep. RIH 7890' - reamed tight spots from 7890' to 7966'. 04/23/01 12:00 AM RIH from 7966" to 10445'. Pump wt.high vis sweep, reciprocate pipe @ 130 rpm - 14 bpm and circ hole clean, slight increase in returns at shaker when sweep came back. RIH from 10445' to 13424'. Ream tight hole from 13424' to 13430', lost eire, reduced pumps to 4.5 bpm and added MI fine seal and nutplug to mud. Regained full returns after 250 bbls loss. Staged pumps up to 10 bpm. RIH to 14090, precautionary reamed last 300'. Pump piggyback wt.high visl low visl wt. high vis sweeps and circ hole clean at 10.5 bpm with 130 rpm. Monitor well, static, pump out 5 stands to 13575'. POH to 5844', worked through several tight spots from 7780' to 6797'. Backream tight spots from 5844' to 5782', POH to 5586' @ midnight. 04/24/01 12:00 AM POH from 5586' to shoe, backreamed tight spot @ 5470', monitor well. POH to BHA. Stand back BHA, LD tools. Service Top Drive and Blocks, adjust brakes on drawworks. RU to run 7" casing, held PJSM. Run casing to 3526'. ) Operations Summary CD1-14 ) Stage pumps up and circ full casing volume @ 10 bpm 880 psi. Reciprocated pipe PUW 145k - SOW 115k. Run casing to 7166'. Stage pumps up to 8 bpm - 710 psi and CBU. Reciprocate pipe PUW 220k - SOW 120k. Run casing to 10653'. Stage pumps up to 8 bpm - 840 psi and CBU. Reciprocated pipe PUW 300K - SOW 120K. Run casing to 12527' @ midnight. **Chuck Scheve (AOGCC) deferred BOP test to run casing. 04/25/01 12:00 AM Continue running 7" csg to 14,073' - FC @ 13,988' (343 jts) had to push last 4 jts. to btm. Staged pumps up to 6 bpm - hole taking fluid @ 1 bpm - slowed pumps to 5 bpm wI full returns - pumped 40 bbls LCM pill- staged pumps up to 8 bpm wI 20 bbls pill out shoe had full returns @ 8 bpm PJSM - Cement 7" csg w I 48 bbls slurry @ 15.8 ppg - Displaced w I 30 bbls fresh water & 507 bbls 10.2 ppg mud 1.5 bbls over calc. displacement - didn't bump plug - floats held - CIP @ 09:08 hrs.- lost pump pressure last 8 bbls of displacement Tear out cmt head & lay down landing jt. Pull wear bushing - install 7" pack-off & test to 5000 psi - install wear bushing PJSM - Lay down 8 1/2" BHA Service pipe skate Lay down 5" drill pipe 04/26/01 12:00 AM Continue lay down 5" drill pipe Change top pipe rams to 3 1/2" X 6" - Change saver sub in top drive Body test BOPE to 5000 psi M/U 6 1/8" bit & 7" csg scraper assembly RIH wI bit & scraper - picking up 3 1/2" drill pipe fl pipe shed to 8883' Pull & std back 15 stds 3 1/2" S grade pipe in derrick - run in hole wI 10 stds 3 1/2" grade G pipe fl derrick Continue RIH wI bit & scraper - picking up 3 1/2" drill pipe f/ pipe shed to 13,654' Cut & slip 60' drill line 04/27101 12:00 AM Clean out cmt fl 13,875' to 13,936' Circ hole clean Flow ckeck - pump dry job - blow down top drive Trip out wI 6 1/8" bit & 7" csg scraper Rig up Schlumberger sheaves PJSM - P/U USIT/GR and Well Tractor RIH wI logging tools to 13,833' tool stopped - ran first logging pass fl 13,800' to 11,983' RIH power up Well Tractor and run logging tools to 13,931' - ran USIT/GR fl 13,931' to 11,983' -log showed good cmtfl 13,931' to 13,370' Rig down Schlumberger Pull wear bushing - set test plug - prep to test BOPE Test BOPE - pipe rams blind rams choke and kill line valves choke manifold valves floor valves manual and IBOP on top drive to 250 psi low and 5000 psi high for 5 mins. . Hydril to 250 psi low and 3500 psi high for 5 mins.- performed accumulator closure test. Pull test plug and install wear bushing. 04/28/01 12:00 AM M/U BHA # 10 Pulse test MWD @ 365' - RIH pick up remaining 3 1/2" drill pipe fl pipe shed - RIH wI DP fl derrick to 13,845' Circ for csg test Test 7" csg to 3500 psi for 30 mins. ') Operations Summary CD1-14 ) RIH to 13,936 - Drill out shoe track wI motor - drill out shoe @ 14,073' - c/o rat hole to 14,090' Drill61/8" hole fl 14,090' to 14,114' ADT-.47 AST-.47 Circ btms up and condition for LOT IFIT Perform FIT to 12.54 ppg EMW wI 9.4 ppg mud @ 1110 psi Displace well to Flow Pro - Observed increase pump pressure when hi vis sweep was going out bit - 4 BPM @ 3800 psi Attempt to continue displacing - pump pressure continuing to increase 2 BPM @ 3950 psi - ck surface equip. - problem,down hole - plugged drill string Monitor well - well static - trip out fl 14114' wI plugged drill string 04/29/01 12:00 AM Continue pull out wI plugged drill string Break off bit - observed 2 jets plugged wI cmt - M/U new bit - reprogram MWD - RIH to 453' - pulse test MWD - continue RIH to 5056'. Circ btms up @ 5056' - pumped 40 bbls 9.2 KCLwl nut plug - Observed very thick - contamiated Flowpro on btms up - dumped same RIH fdl 5056' to 10,017' Cirs btms up @ 10,017' - pumped 40 bbls KCLw/nut plug - observed very thick - contamiated Flopro on btms up -dumped same RIH fl 10,017' to 14,044' Cirs btms up @ 14,044' - pumped 40 bbls KCLw/nut plug - once again observed very thick and contaminated Flopro on btms up & dumped same - * Note hole started taking fluid as the thick Flopro was being circulated up the hole - pump pressure increased 04/30101 12:00 AM Continue circ out contaminated Flo Pro - loses stopped after comtaminated Flo Pro out of hole - pumping @ 116 gpm 1140 psi Circ and monitor loss rate while pumping - no losses Monitor well on trip tank - no losses Rig up & repeat FIT - 12.5 ppg EMW Cut and slip drill line 60' Inject old mud - clean mud pit and lines for new FloPro - take on new Flo Pro PJSM - Displace well wI 9.2 ppg Flo Pro - observe well - static - clean surface equip Drill 6 1/8" hole fl 14,114' to 14,519' 6847' TVD - ADT- 5.03 AST- 2.37 05/01/01 12:00 AM Drill fl 14,519' to 14,630' Hole started taking fluid @ 14,630' - losses @ 120 B/H - slowed pump rate - losses slowed to 40 B/H - Mix & pump 40 bbls - 15 ppb CAC03 pill Drill fl 14,630' to 14,670' - loss rate 150 - 80 B/H - pumped 40 bbls - 40 ppb CAC03 pill while drilling Monitor losses @ slowed pump rater 2.8 b/m @ 1310 psi -losses 30 -10 b/h - mix 20 bbls 65 ppb CAC03 pill and spot on btm - monitor well - stable Pump out to 7'1 shoe - monitor well - stable Spot 20 bbls 65 ppb CAC03 pill - attempt to squeeze into formation - pumped 7 bbls LCM pill into formation - starting pressure 570 psi final pressure 690 psi - 11.16 EMW. Drill fl 14,670' to 14,807' - 6845' TVD - Hole still taking fluid - 40 to 145 bbls/hr- observed well breathing - 18 % flow to 1 % flow in 10 minutes Losses increased f/44 b/h to 144 b/h - Slow pumps rate to 5 b/m @ 3120 psi - lose rate 45 b/h - mix & pump LCM pill - circ btms up - no hydrocarbons Drill f/14807' to 14837' - losses increased to 156 b/h - well breathing 18% flow to 1 % flow in 10 mins Circ @ 2.5 b/m - losses 33 b/h - mix 40 bbls KCL pill wI CAC03 - Mix II - MI fine @ 60 ppb & pump Drill fl 14837' to 14900' - loss rate 145 b/h ) Operations Summary CD1-14 ) Drilling torque increased fl 12000 to 16000 - circ out LCM sweep across shakers and conditon mud Shut down pumps - well flowing - perform Exhale test for breathing well - SIDDP - 620 psi SICP - 410 psi - bleed off 13 bbls through choke - pressure drop to 0 psi when choke was opened - flow back rate 1 b/m - Shut in well - SIDPP - 480 psi SICP 280 psi Blow down choke manifold and line up to drill - total losses for past 24 hrs. 733 bbls 05/02/01 12:00 AM Drill f/14,900' to 15,350' - 6843 TVD - ADT - 7.02 AST- 2.33 - hole taking fluid @ 50 b/h average - total losses 353 bbls - well breathing on connections - gaining 24 - 27 bbls Drill fl 15,350' to 15,643' - hole taking fluid @ 46 b/h average - well breathing on connections - gaining 24 - 27 bbls. Monitor well breathing - flow rate fl 19% to 6 % in 30 mins - flowed back 69.9 bbls - made connection & drill ahead - observerd no hydrocarbons on btms up Drill fl 15,643' to 15,848' - 6849' TVD - Since 1900 hrs ADT- 8.01 AST- .66 - hole taking fluid @ 46 b//h average - well breathing on connections - gaining 24 - 27 bbls. - Total losses past 24 hrs. 724 bbls. 05/03/01 12:00 AM Drill fl 15,848' to 16,400' - 6848' TVD - ADT - 8.27 AST - 2.69 - hole taking fluid @ 32 B/H average - hole still breathing on connections - 24 to 30 bbls gain Drill fl 16,400' to 16,775' - 6851' TVD - ADT - 8.36 AST- 3.97 - hole taking fluid @ 23 B/H average - hole still breathing on connections @ same rate - T otallosses past 24 hrs. - 455 bbls 05/04/01 12:00 AM Drill fl 16,775' to 17,120' - 6854' TVD - ADT-7.38 AST - 3.43 - hole taking 8.5 B/H average - well still breathing on connections Circ btms up for trip Perform Exhale Test as per RP - ISIDPP - 560 ISICP - 440 - Flow back well through choke 30 bbls - flow rate decreased fl 5 bbls in 2 mins. to 5 bbls in 6 mins. - 2nd shut in SIDPP - 370 SICP - 170 - open well and monitor on trip tank for 1 hr. Pump out to 1" shoe - good hole fill Circ btms up @ 7" shoe - no hydrocarbons on btms up - Mud wt - 9.4 ppg - blow down top drive Monitor well on trip tank - flow rate 16% to 2% in 6 mins.- gained 19.5 bbls in first hr. - gained 5.8 bbls second hr. 05/05/01 12:00 AM Pmup out fl 7" shoe to 11,940' - 20 stds - hole fill good Monitor well slight breathing flow @ 1 % gained 3 bbls in 1 hr. Attempt to pull out circ on trip tank - pulled 5 stds to 11,440" - in correct hole fill - swabbed 1 bbl - monitor well hole static - pump out fl 11 ,440 to 9858' - hole fill good Monitor well - well breathing - flow @ 1 % - Unable to trip out with out pumping for proper hole fill- made decision to RIH and drill - Obtained extension from AOGCC on BOP test until TD of well - RIH to 7" shoe - monitor well - well breathing Circ btms up - no hydrocarbons Drill f/17,120' to 17,199' - Hole taking fluid @ 200 B/H Reduce pump rate - circ Mix & pump LCM pill Drill f/17, 199' to 17,212' Perform Exhale test for breathing well - SIDPP 610 SICP 300 - flow back 20 bbls through choke flow 1 bbl in 27 sec to 1 bbl in 1 min 30 sec flow rate - shut in - SIDPP 450 SICP 280 Drill fl 17212' to 17420' 6858 TVD - ADT 5.61 AST 2.43 - hole taking fluid @ 154 B/H average - breathing on connections - gaining average 20 bbls - Totallosses last 24 hrs. 864 bbls - ***NOTE: had an accident - Doyon floor hand Donald Petrushka - crush i ) Operations Summary CD1-14 ) 05/06/01 12:00 AM Drill f/ 17,420' to 17,914' - 6848' TVD - ADT - 8.04 AST - 1.87 - lost 467 bbls - Average 38 b/h - Drill f/17,914' to 18,348' - 6844' TVD - ADT - 8.13 AST- .96 - Lost 400 bbls - Average 36 b/h. Well still breathing on connections - 20 bbls Average gain. Total losses to formation to date - 2840 bbls 05/07/01 12:00 AM Drill f/ 18,348' to 18,640' - 6831' TVD - ADT - 7.66 AST- .32 - hole taking fliud while drilling 22 b/h - breathing on connections - gaining 20 - 25 bbls Drill f/ 18,640' to 18,939' TD - 6814' TVD - ADT- 8.17 - hole taking fluid while drilling 49 b/h - reathing on connections gaining 20 -25 bbls - Total losses past 24 hrs. 872 bbls. - TOTAL to Date - 3712 bbls Pump low/high vis sweep & circ hole clean Shut down pumps - monitor well at flow line - flow rate 20 % to 13 % in 18 mins. gained 100 bbls in 30 mins. 05/08/01 12:00 AM Circ btms up - hole took 103 bbls - no oil or gas on btms up Wiper trip - pump out to 14,044' Kill Drill - Perform Exhale test - SIDPP 330 SICP - 160 - Open choke & flow 9.6bbls in 30 mins. - SIDPP - 210 SICP 60 _ open well Monitor well - gained 3.8 bbls Cut & slip 60' drill line RIH to 18,939' PJSM - Change well over to 9.2 ppg brine - losses while displacing 20+ bbl/hr. through most of displacement - nearly full returns near end of displacement Monitor well, fluid level dropping slowly, spot 60 bbls Hi Vis pill, Blow down top drive 05/09/01 12:00 AM POH to 17285'. Pump 60 bbls of clean Flo-Vis pill and displace into openhole, monitor well, stable. POH to 13985', monitor well, static losses 6 bph. POH to 11280' standing back pipe, continue to POH, laid down 349 joints of 3-1/2" drill pipe. LD hwdp, flush and LD BHA, clear tools from floor. PU wash sub and flush out BOP stack, pull wear bushing. Test BOPE, pipe rams, blind rams, choke and kill line valves, floor safety valves, manual and mud saver valve on top drive 250/5000 psi. Annular preventor 250/3500 psi. RU to run 4-1/2" tubing, held safety meeting with rig team. MU WLEG - pup - XN nipple - packer assy - and PU 4-1/2" tubing. 05/10/01 12:00 AM PU 4-1/2" tubing, RIH with Completion assembly to 11044'. RU Cameo, MU SSSV, attatch and test control lines to 5000 psi, 10 min. Continue to PU tubing, RIH banding control lines. MU tubing hanger and LJa, strip control lines thru hanger and test fittings to 5000 psi. Land tubing @ 13421', top of packer @ 13365'. RILDS, LD LJa and set TWC, MU LJb and test M/M hanger seals to 5000 psi, LD LJb. Hole taking 4 bph. ND BOPE, terminate control lines and test to 5000 psi NU and test tree to 5000 psi. Rig up lubricator and pull TWC. RU circ manifold and lines. Conventionally circ 60 bbls of 9.6 ppg brine followed by 195 bbls of treated 9.6 ppg brine @ 3 bpm with rig pumps. Line up to Dowell and begin pumping diesel for tubing displacement and casing freeze protection. 05/11/01 12:00 AM Finished displacing diesel, 275 bbls total. RU and drop ball and rod, waited 30 min and attempted to set packer, ball not on seat. Made seveal attempts to set packer, ball not on seat. ') Operations Summary CD1-14 ) Drain and remove standpipe from wellhead. RU Howco lubricator and BOP's, test lubricator to 3500 psi. RIH with 3.70" belled guide dressed with inset IB to SSSV @ 2298'. POH. IB indicated tools had tagged top of rod. Dressed 3.70" belled guide with overshot Tested tubing to 3550 psi, bled off to 3350 psi in 30 min. Tested backside to 3550 psi, 3500 psi after 30 min. Bled back casing and lines to bleed off tank Flushed lubricator and lines, rig down Halliburton. RU FMC lubricator and set BPV, RD lubricator and secure wellhead and cellar. RU and LD 240 joints of 3-1/2" drill pipe from derrick, clear tools from floor and empty pipe shed. Released rig from well @ midnight. Client...... ...... ...~...: Phillips Alaska, Inc Field. ........ .... ..... ..: Colville River Well.....................: CDl-14 API number........ ..... ..: 50-103-20371-00 Engineer...... ...........: Arnazigo COUNTY: . . . . . . . . . . . . . . . . . .: Doyon 19 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.. ....... ..: Mason & Taylor ----- Depth reference -------------------~--- Permanent datum.. ... .....: MEAN SEA LEVEL Depth reference.. ........: Drill Floor GL above permanent. .... ..: 19.50 ft KB above permanent...... .:, DF above permanent.. .....: 56.30 ft ----- Vertical section origin---------------- Latitude (+N/S-)..... ....: 0.00 ft Departure (+E/W-)... ... ..: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-)... ......: -999.25 ft Departure (+E/W-). .......: -999.25 ft ANADRILL SCHLUMBERGER Survey report Azimuth from rotary table to target: 150.09 degrees All surveys IFRR corrected 8-May-2001 05:41:26 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 9 25-Feb-01 08-May-01 216 0.00 ft 18938.00 ft ~/ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date..... .......: 01-Apr-2001 Magnetic field strength..: 1147.25 HCNT Magnetic dec (+E/W-) .....: 25.47 degrees Magnetic dip.............: 80.55 degrees ----- MWD survey Reference Reference G..............: Reference H..............: Reference Dip............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1147.25 HCNT 80.55 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.48 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N). .......: No degree: 0.00 -- ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 2 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 90.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 83.00 0.30 157.00 83.00 83.00 0.22 -0.20 0.08 0.22 157.00 0.36 MWD_M 3 257.00 4.75 139.00 174.00 256.79 7.74 -6.06 4.99 7.85 140.52 2.57 MWD_M 4 379.00 10.50 143.00 122.00 377.66 23.74 -18.76 15.00 24.02 141.35 4.73 MWD_M 5 476.00 11.87 137.69 97.00 472.82 42.26 -33.20 27.04 42.82 140.84 1.77 MWD_M 6 566.00 14.17 134.87 90.00 560.50 61.93 -47.82 41.08 63.04 139.33 2.65 MWD_M 7 656.00 16.02 133.69 90.00 647.39 84.48 -64.17 57.87 86.41 137.96 2.08 MWD_M - ~' 8 746.00 16.24 130.23 90.00 733.85 108.23 -80.87 76.46 111.29 136.61 1.10 MWD_M 9 836.00 15.87 129.17 90.00 820.34 131.56 -96.78 95.60 136.04 135.35 0.52 MWD_M 10 925.00 17.13 126.70 89.00 905.67 154.96 -112.30 115.55 161.13 134.18 1.62 MWD_M 11 1015.00 19.97 120.98 90.00 990.99 180.56 -128.13 139.36 189.31 132.60 3.74 MWD_M 12 1109.00 24.56 113.42 94.00 1077.98 210.27 -144.17 171.07 223.72 130.12 5.75 MWD_M 13 1205.00 29.89 108.19 96.00 1163.33 244.11 -159.58 212.14 265.46 126.95 6.08 MWD_M 14 1300.00 33.41 102.16 95.00 1244.21 279.27 -172.49 260.22 312.20 123.54 4.98 MWD_M 15 1395.00 36.59 99.06 95.00 1322.02 314.61 -182.46 313.77 362.96 120.18 3.83 MWD_M 16 1491.00 41.99 96.13 96.00 1396.30 351.53 -190.40 374.00 419.68 116.98 5.95 MWD_M 17 1681.00 50.14 91.75 190.00 1528.05 427.35 -199.43 510.35 547.93 111.34 4.60 MWD_M 18 1776.00 54.65 91.25 95.00 1586.01 466.55 -201.39 585.56 619.23 108.98 4.77 MWD_M 19 1871.00 58.09 91.49 95.00 1638.61 507.62 -203.28 664.63 695.02 107.01 3.63 MWD_M 20 1966.00 62.01 91.11 95.00 1686.03 550.26 -205.15 746.91 774.57 105.36 4.14 MWD_M 21 2062.00 63.67 91.03 96.00 . 1729.85 594.22 -206.74 832.30 857.59 103.95 1.73 MWD_M 917.70 940.97 102.77 0.84 MWD_M ------- 22 2157.00 64.39 90.65 95.00 1771.45 637.89 -207.99 23 2252.00 65.04 90.92 95.00 1812.03 681.74 -209.17 1003.59 1025.16 101.77 0.73 MWD_M 24 2347.00 65.87 90.74 95.00 1851.49 725.91 -210.42 1089.99 1110.12 100.93 0.89 MWD_M 25 2443.00 65.05 90.37 96.00 1891.36 770.19 -211.27 1177.32 1196.12 100.17 0.92 MWD_M 26 2532.00 65.21 91.38 89.00 1928.79 811.51 -212.50 1258.05 1275.87 99.59 1.05 MWD_M 27 2633.00 65.33 91.89 101.00 1971.05 859.51 -215.12 1349.75 1366.79 99.06 0.47 MWD_M 28 2729.00 65.74 92.16 96.00 2010.80 905.73 -218.21 1437.08 1453.55 98.63 0.50 MWD_M 29 2824.00 66.41 91.93 95.00 2049.33 951.69 -221.31 1523.86 1539.85 98.26 0.74 MWD_M 30 2919.00 65.19 91.29 95.00 2088.27 996.99 -223.74 1610.48 1625.94 97.91 1.42 MWD_M ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 3 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) ( ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 3014.00 65.58 91.54 95.00 2127.84 1041.89 -225.87 1696.82 1711.78 97.58 0.48 MWD_M 32 3109.00 64.92 92.13 95.00 2167.61 1087.28 -228.64 1783.04 1797.64 97.31 0.89 MWD_M 33 3204.00 65.54 92.03 95.00 2207.42 1132.98 -231.77 1869.25 1883.56 97.07 0.66 MWD_M 34 3299.00 65.86 90.88 95.00 2246.51 1178.04 -233.96 1955.80 1969.74 96.82 1.15 MWD_M 35 3394.00 65.23 91.70 95.00 2285.84 1222.84 -235.91 2042.25 2055.83 96.59 1.03 MWD_M 36 3490.00 65.65 91.47 96.00 2325.74 1268.45 -238.32 2129.53 2142.83 96.39 0.49 MWD_M 37 3534.54 65.53 91.52 44.54 2344.15 1289.59 -239.38 2170.08 2183.24 96.29 0.29 MWD_M ~ 38 3623.00 64.27 90.60 88.46 2381.67 1330.81 -240.87 2250.17 2263.02 96.11 1.71 MWD 39 3717.00 63.54 92.15 94.00 2423.02 1374.64 -242.89 2334.56 2347.16 95.94 1.67 MWD 40 3811.00 63.00 91.81 94.00 2465.30 1419.00 -245.79 2418.46 2430.92 95.80 0.66 MWD 41 3905.00 62.61 92.39 94.00 2508.26 1463.31 -248.85 2502.02 2514.36 95.68 0.69 MWD 42 3999.00 62.38 92.06 94.00 2551.67 1507.66 -252.09 2585.33 2597.59 95.57 0.40 MWD 43 4093.00 63.40 92.42 94.00 2594.51 1552.19 -255.36 2668.93 2681.12 95.47 1.14 MWD 44 4185.00 64.40 90.90 92.00 2634.99 1595.43 -257.75 2751.51 2763.56 95.35 1.84 MWD 45 4277.00 64.21 90.97 92.00 2674.87 1637.94 -259.10 2834.41 2846.22 95.22 0.22 MWD 46 4374.00 64.55 90.44 97.00 2716.82 1682.48 -260.18 2921.86 2933.42 95.09 0.60 MWD 47 4458.00 64.80 90.58 84.00 2752.75 1720.93 -260.86 2997.79 3009.11 94.97 0.33 MWD 48 4564.00 65.24 90.54 106.00 2797.51 1769.65 -261.79 3093.87 3104.92 94.84 0.42 MWD 49 4661.00 65.16 90.49 97.00 2838.20 1814.24 -262.59 3181.92 3192.73 94.72 0.09 MWD 50 4756.00 63.88 91.30 95.00 2879.07 1858.16 -263.92 3267.66 3278.30 94.62 1.55 MWD 51 4851.00 63.22 91.76 95.00 2921.38 1902.52 -266.19 3352.69 3363.24 94.54 0.82 MWD --/ 52 4946.00 62.98 91.42 95.00 2964.36 1946.79 -268.54 3437.38 3447.85 94.47 0.41 MWD 53 5041.00 63.11 91.90 95.00 3007.43 1991.12 -271.00 3522.02 3532.43 94.40 0.47 MWD 54 5136.00 63.29 91.84 95.00 3050.26 2035.78 -273.76 3606.77 3617.14 94.34 0.20 MWD 55 5231.00 63.18 90.71 95.00 3093.04 2079.70 -275.65 3691.57 3701.85 94.27 1.07 MWD 56 5326.00 62.99 91.15 95.00 3136.05 2123.12 -277.03 3776.27 3786.41 94.20 0.46 MWD 57 5422.00 62.98 89.58 96.00 3179.65 2166.24 -277.57 3861.79 3871.75 94.11 1.46 MWD 58 5517.00 62.56 89.85 95.00 3223.12 2208.00 -277.15 3946.26 3955.98 94.02 0.51 MWD 59 5613.00 62.41 89.61 96.00 3267.47 2250.10 -276.75 4031.40 4040.88 93.93 0.27 MWD 60 5708.00 63.71 90.31 95.00 3310.51 2292.28 -276.69 4116.08 4125.37 93.85 1.52 MWD ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 4 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5802.00 63.97 90.42 94.00 3351.96 2334.82 -277.23 ,4200.45 4209.59 93.78 0.30 MWD 62 5898.00 63.78 90.64 96.00 3394.23 2378.49 ~278.03 4286.64 4295.65 93.71 0.29 MWD 63 5993.00 63.95 90.19 95.00 3436.07 2421.55 -278.65 4371.93 4380.80 93.65 0.46 MWD 64 6088.00 63.80 90.40 95.00 3477.90 2464.46 -279.08 4457.22 4465.95 93.58 0.25 MWD 65 6184.00 64.04 90.71 96.00 3520.11 2508.18 -279.92 4543.44 4552.06 93.53 0.38 MWD 66 6279.00 64.24 90.69 95.00 3561.55 2551.71 -280.96 4628.92 4637.44 93.47 0.21 MWD 67 6374.00 64.63 89.96 95.00 3602.54 2594.86 -281.45 4714.62 4723.01 93.42 0.81 MWD - 68 6469.00 64.72 90.25 95.00 3643.18 2637.81 -281.61 4800.49 4808.74 93.36 0.29 MWD 69 6564.00 64.76 89.92 95.00 3683.72 2680.76 -281.73 4886.40 4894.52 93.30 0.32 MWD 70 6658.00 64.25 92.59 94.00 3724.18 2724.66 -283.59 4971.22 4979.30 93.26 2.62 MWD 71 6755.00 64.05 92.42 97.00 3766.48 2771.46 -287.40 5058.43 5066.59 93.25 0.26 MWD 72 6849.00 64.31 93.17 94.00 3807.42 2817.18 -291.53 5142.94 5151.20 93.24 0.77 MWD 73 6945.00 64.40 93.29 96.00 3848.97 2864.49 -296.41 5229.35 5237.74 93.24 0.15 MWD 74 7040.00 64.67 92.82 95.00 3889.81 2911.16 -300.98 5315.00 5323.51 93.24 0.53 MWD 75 7135.00 64.77 93.25 95.00 3930.38 2957.87 -305.53 5400.78 5409.42 93.24 0.42 MWD 76 7231.00 64.60 93.38 96.00 3971.43 3005.42 -310.54 5487.42 5496.20 93.24 0.22 MWD 77 7324.00 64.90 93.22 93.00 4011.10 3051.49 -315.39 5571.39 5580.31 93.24 0.36 MWD 78 7420.00 64.64 92.75 96.00 4052.02 3098.66 -319.91 5658.11 5667.15 93.24 0.52 MWD 79 7515.00 64.71 92.59 95.00 4092.66 3144.90 -323.91 5743.89 5753.02 93.23 0.17 MWD 80 7612.00 64.44 92.18 97.00 4134.30 3191.70 -327.55 5831.42 5840.61 93.21 0.47 MWD 81 7707.00 63.58 92.20 95.00 4175.93 3237.08 -330.82 5916.75 5925.99 93.20 0.91 MWD '~ 82 7802.00 62.85 92.19 95.00 4218.75 3282.15 -334.07 6001.49 6010.78 93.19 0.77 MWD 83 7897.00 62.37 92.54 95.00 4262.45 3327.19 -337.55 6085.77 6095.13 93.17 0.60 MWD 84 7992.00 63.60 92.73 95.00 4305.60 3372.72 -341.44 6170.31 6179.75 93.17 1.31 MWD 85 8087.00 63.21 92.59 95.00 4348.13 3418.45 -345.38 6255.17 6264.70 93.16 0.43 MWD 86 8182.00 63.21 92.29 95.00 4390.95 3463.83 -348.99 6339.90 6349.50 93.15 0.28 MWD 87 8277.00 63.12 91.98 95.00 4433.83 3508.81 -352.15 6424.61 6434.25 93.14 0.31 MWD 88 8373.00 62.96 91.99 96.00 4477.36 3554.02 -355.11 6510.12 6519.80 93.12 0.17 MWD 89 8468.00 62.80 91.86 95.00 4520.66 3598.62 -357.95 6594.63 6604.34 93.11 0.21 MWD 90 8563.00 62.76 91.44 95.00 4564.12 3642.83 -360.38 6679.07 6688.79 93.09 0.40 MWD ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 5 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (de g) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8658.00 62.73 91.14 95.00 4607.62 3686.58 -362.29 6763.51 6773.20 93.07 0.28 MWD 92 8752.00 62.38 91.02 94.00 4650.95 3729.54 -363.86 6846.91 6856.57 93.04 0.39 MWD 93 8847.00 62.05 90.92 95.00 4695.23 3772.67 -365.28 6930.95 6940.57 93.02 0.36 MWD 94 8942.00 63.11 91.52 95.00 4738.98 3816.27 -367.08 7015.25 7024.85 93.00 1.25 MWD 95 9038.00 62.85 91.51 96.00 4782.59 3860.86 -369.34 7100.74 7110.34 92.98 0.27 MWD 96 9133.00 62.35 91.52 95.00 4826.31 3904.83 -371.57 7185.06 7194.66 92.96 0.53 MWD 97 9227.00 63.78 91.42 94.00 4868.89 3948.47 -373.72 7268.83 7278.43 92.94 1.52 MWD -- 98 9323.00 63.55 91.41 96.00 4911.48 3993.20 -375.84 7354.84 7364.44 92.93 0.24 MWD 99 9418.00 62.88 91.44 95.00 4954.29 4037.30 -377.95 7439.62 7449.21 92.91 0.71 MWD 100 9513.00 64.42 91.34 95.00 4996.45 4081.53 -380.02 7524.72 7534.31 92.89 1.62 MWD 101 9608.00 63.78 91.16 95.00 5037.95 4125.74 -381.88 7610.16 7619.73 92.87 0.69 MWD 102 9703.00 63.00 90.97 95.00 5080.50 4169.46 -383.46 7695.08 7704.63 92.85 0.84 MWD 103 9798.00 62.76 91.33 95.00 5123.81 4213.08 -385.16 7779.62 7789.15 92.83 0.42 MWD 104 9893.00 62.80 91.52 95.00 5167.26 4257.02 -387.26 7864.07 7873.60 92.82 0.18 MWD 105 9986.00 62.59 92.04 93.00 5209.92 4300~43 -389.83 7946.67 7956.22 92.81 0.55 MWD 106 10083.00 63.74 91.28 97.00 5253.71 4345.74 -392.33 8033.18 8042.76 92.80 1.38 MWD 107 10181.00 63.37 91.29 98.00 5297.35 4391.18 -394.30 8120.91 8130.47 92.78 0.38 MWD 108 10276.00 64.25 91,.74 95.00 5339.28 4435.63 -396.55 8206.12 8215.70 92.77 1.02 MWD 109 10371.00 63.98 91.16 95.00 5380.76 4480.11 -398.72 8291.56 8301.15 92.75 0.62 MWD 110 10467.00 66.01 91.89 96.00 5421.33 4525.49 -401.04 8378.53 8388.12 92.74 2.22 MWD 111 10561.00 65.88 91.33 94.00 5459.65 4570.36 -403.45 8464.33 8473.94 92.73 0.56 MWD 5498.58 4614.97 -405.07 8550.97 8560.56 92.71 0.52 MWD - 112 10656.00 65.74 90.81 95.00 113 10751.00 65.96 90.38 95.00 5537.44 4658.97 -405.97 8637.66 8647.19 92.69 0.47 MWD 114 10846.00 66.10 90.51 95.00 5576.04 4702.84 -406.64 8724.46 8733.93 92.67 0.19 MWD 115 10941.00 66.21 90.05 95.00 5614.44 4746.53 -407.06 8811.35 8820.75 92.65 0.46 MWD 116 11036.00 65.81 90.24 95.00 5653.07 4790.00 -407.28 8898.14 8907.46 92.62 0.46 MWD 117 11132.00 65.97 90.47 96.00 5692.28 4834.16 -407.83 8985.77 8995.02 92.60 0.27 MWD 118 11227.00 65.81 92.26 95.00 5731.09 4879.18 -409.89 9072.45 9081.70 92.59 1.73 MWD 119 11322.00 65.94 91.68 95.00 5769.92 4924.97 -412.87 9159.10 9168.40 92.58 0.57 MWD 120 11418.00 65.08 91.34 96.00 5809.72 4970.51 -415.17 9246.43 9255.75 92.57 0.95 MWD ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 6 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 121 11513.00 64.09 91.58 95.00 5850.49 5015.18 -417.36 9332.21 9341.54 92.56 1.07 MWD 122 11608.00 63.52 91.79 95.00 5892.42 5059.84 ~419.87 9417.42 9426.77 92.55 0.63 MWD 123 11704.00 63.23 91.02 96.00 5935.45 5104.44 -421.97 9503.21 9512.57 92.54 0.78 MWD 124 11800.00 64.91 91.58 96.00 5977.42 5149.18 -423.93 9589.52 9598.88 92.53 1.83 MWD 125 11894.00 65.40 90.75 94.00 6016.92 5193.21 -425.67 9674.80 9684.16 92.52 0.96 MWD 126 11990.00 66.18 90.24 96.00 6056.29 5237.52 -426.42 9762.35 9771.66 92.50 0.95 MWD 127 12084.00 65.65 89.66 94.00 6094.65 5280.25 -426.35 9848.17 9857.39 92.48 0.80 ~ j MWD 128 12153.00 66.63 91.60 69.00 6122.56 5312.31 -427.04 9911.26 9920.46 92.47 2.94 MWD 129 12248.00 66.09 94.58 95.00 6160.66 5359.70 -431.73 9998.15 10007.47 92.47 2.93 MWD 130 12342.00 65.04 94.62 94.00 6199.55 5408.18 -438.59 10083.45 10092.99 92.49 1.12 MWD 131 12437.00 64.57 95.36 95.00 6239.99 5457.37 -446.07 10169.09 10178.87 92.5~ 0.86 MWD 132 12533.00 64.24 94.25 96.00 6281.46 5506.67 -453.32 10255.36 10265.38 92.53 1.10 MWD 133 12628.00 63.80 94.90 95.00 6323.08 5555.02 -460.13 10340.49 10350.72 92.55 0.77 MWD 134 12723.00 63.50 93.76 95.00 6365.24 5602.92 -466.56 10425.38 10435.81 92.56 1.12 MWD 135 12818.00 61.85 93.40 95.00 6408.85 5649.49 -471.83 10509.61 10520.19 92.57 1.77 MWD 136 12911.00 61.38 94.73 93.00 6453.06 5695.21 -477.63 10591.22 10601.98 92.58 1.36 MWD 137 13007.00 61.07 95.06 96.00 6499.28 5743.24 -484.81 10675.06 10686.06 92.60 0.44 MWD 138 13103.00 61.63 95.22 96.00 6545.30 5791.62 -492.36 10758.96 10770.22 92.62 0.60 MWD 139 13198.00 62.48 95.17 95.00 6589.82 5839.89 -499.96 10842.54 10854.06 92.64 0.90 MWD 140 13292.00 62.91 96.58 94.00 6632.94 5888.73 -508.51 10925.62 10937.45 92.66 1.41 MWD 141 13329.00 63.04 96.96 37.00 6649.76 5908.42 -512.40 10958.35 10970.33 92.68 0.98 MWD -- 142 13360.00 63.42 98.76 31.00 6663.72 5925.37 -516.18 10985.77 10997.89 92.69 5.33 MWD 143 13388.00 63.80 100.75 28.00 6676.17 5941.38 -520.43 11010.49 11022.78 92.71 6.51 MWD 144 13427.00 64.25 103.01 39.00 6693.25 5964.74 -527.65 11044.79 11057.39 92.74 5.34 MWD 145 13457.00 64.38 105.14 30.00 6706.25 5983.51 -534.22 11071.02 11083.90 92.76 6.41 MWD 146 13483.00 64.87 106.40 26.00 6717.40 6000.32 -540.61 11093.62 11106.79 92.79 4.77 MWD 147 13519.00 65.80 109.89 36.00 6732.42 6024.65 -550.80 11124.70 11138.33 92.83 9.18 MWD 148 13549.00 66.66 112.11 30.00 6744.52 6045.96 -560.64 11150.33 11164.42 92.88 7.35 MWD 149 13578.00 67.79 114.35 29.00 6755.74 6067.35 -571.19 11174.90 11189.49 92.93 8.12 MWD 150 13613.00 68.80 117.15 35.00 6768.69 6094.20 -585.31 11204.18 11219.46 92.99 7.97 MWD ANADRILL SCHLUMBERGER Survey Report 8-May-2001 05:41:26 Page 9 of 9 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- ---------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 211 18467.00 92.64 149.09 92.00 6839.45 10908.77 -4707.35 13694.07 14480.56 108.97 1.01 MWD 212 18564.00 92.64 149.30 97.00 6834.98 11005.66 -4790.57 13743.69 14554.68 109.22 0.22 MWD 213 18659.00 92.95 149.67 95.00 6830.35 11100.54 -4872.32 13791.87 14627.21 109.46 0.51 MWD 214 18754.00 93.39 151.53 95.00 6825.10 11195.39 -4954.95 13838.43 14698.77 109.70 2.01 MWD 215 18848.00 93.57 152.69 94.00 6819.39 11289.15 -5037.88 13882.32 14768.18 109.95 1.25 MWD 216 18939.00 93.57 152.69 91.00 6813.73 11379.88 -5118.58 13923.99 14835.00 110.18 0.00 MWD Proj ectE - -- Client...... ...... ..... ..: Phillips Alaska, Inc Field............... ... ..: Colville River Well. . . . . . . . . . . . . . . . . . . . .: CDl-14PH API number........ .......: 50-103-20371-70 Engineer............ .....: Dammeyer COUNTY: . . . . . . . . . . . . . . . . . .: Doyon 19 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions... ..: Minimum curvature Method for DLS.. ... .... ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.. ... ... ..: MEAN SEA LEVEL Depth reference.. ... ... ..: Drill Floor GL above permanent.. ... ..: 19.50 ft KB above permanent..... ..: DF above permanent.. ... ..: 56.30 ft ----- Vertical section origin---------------- Latitude (+N/S-). ........: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-). ........: -999.25 ft Departure (+E/W-) ..... ...: -999.25 ft ANADRILL SCHLUMBERGER Survey report Azimuth from rotary table to target: 92.39 degrees All survey type "MWD" is corrected using IIFR [(c)2001 Anadrill IDEAL ID6_1C_08] 9-Apr-2001 16:37:10 Spud date.. . . . . . . . . . . . . . . : Last survey date.. .......: Total accepted surveys...: MD of first survey.......: MD of last survey. ... ....: Page 1 of 6 25-Feb-01 09-Apr-01 148 0.00 ft 14003.00 ft .~- ---~- Geomagnetic data ---~------------------ Magnetic model.... .......: BGGM version 2000 Magnetic date..... .......: 01-Apr-2001 Magnetic field strength..: 1147.25 HCNT Magnetic dec (+E/W-). ....: 25.48 degrees Magnetic dip.............: 80.55 degrees ----- MWD survey Reference Reference G....... .......: Reference H.... ..........: Reference Dip............: Tolerance of G...........: Tolerance of H.... .......: Tolerance of Dip.. ... ..~.: Criteria --------- 1002.68 mGal 1147.25 HCNT 80 . 55 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec(+E/W-) .....: 25.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr 1+E/W-) ....: 25.48 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N). .......: No degree: 0.00 --~. [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 16:37:10 Page 2 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f} type type - -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 90.50 0.00 O~OO 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 83.00 0.30 157.00 83.00 83.00 0.09 -0.20 0.08 0.22 157.00 0.36 MWD_M 3 257.00 4.75 139.00 174.00 256.79 5.24 -6.06 4.99 7.85 140.52 2.57 MWD_M 4 379.00 10.50 143.00 122.00 377.66 15.77 -18.76 15.00 24.02 141.35 4.73 MWD_M 5 476.00 11.87 137.69 97.00 472.82 28.40 -33.20 27.04 42.82 140.84 1.77 MWD_M 6 566.00 14.17 134.87 90.00 560.50 43.04 -47.82 41.08 63.04 139.33 2.65 MWD_M 7 656.00 16.02 133.69 90.00 647.39 60.49 -64.17 57.87 86.41 137.96 2.08 MWD_M - -- 8 746.00 16.24 130.23 90.00 733.85 79.76 -80.87 76.46 111.29 136.61 1.10 MWD_M 9 836.00 15.87 129.17 90.00 820.34 99.56 -96.78 95.60 136.04 135.35 0.52 MWD_M 10 925.00 17.13 126.70 89.00 905.67 120.13 -112.30 115.55 161.13 134.18 1.62 MWD_M 11 1015.00 19.97 120.98 90.00 990.99 144.58 -128.13 139.36 189.31 132.60 3.74 MWD_M 12 1109.00 24.56 113.42 94.00 1077.98 176.93 -144.17 171.07 223.72 130.12 5.75 MWD_M 13 1205.00 29.89 108.19 96.00 1163.33 218.61 -159.58 212.14 265.46 126.95 6.08 MWD_M 14 1300.00 33.41 102.16 95.00 1244.21 267.19 -172.49 260.22 312.20 123.54 4.98 MWD_M 15 1395.00 36.59 99.06 95.00 1322.02 321.10 -182.46 313.77 362.96 120.18 3.83 MWD_M 16 1491.00 41.99 96.13 96.00 1396.30 381.62 -190.40 374.00 419.68 116.98 5.95 MWD_M 17 1681.00 50.14 91.75 190.00 1528.05 518.22 -199.43 510.35 547.93 111.34 4.60 MWD_M 18 1776.00 54.65 91.25 95.00 1586.01 593.45 -201.39 585.56 619.23 108.98 4.77 MWD_M 19 1871.00 58.09 91.49 95.00 1638.61 672.53 -203.28 664.63 695.02 107.01 3.63 MWD_M 20 1966.00 62.01 91.11 95.00 1686.03 754.81 -205.15 746.91 774.57 105.36 4.14 MWD_M 21 2062.00 63.67 91.03 96.00 1729.85 840.20 -206.74 832.30 857.59 103.95 1.73 MWD_M '---- 22 2157.00 64.39 90.65 95.00 1771.45 925.57 -207.99 917.70 940.97 102.77 0.84 MWD_M 23 2252.00 65.04 90.92 95.00 1812.03 1011.44 -209.17 1003.59 1025.16 101.77 0.73 MWD_M 24 2347.00 65.87 90.74 95.00 1851.49 1097.82 -210.42 1089.99 1110.12 100.93 0.89 MWD_M 25 2443.00 65.05 90.37 96.00 1891.36 1185.10 -211.27 1177.32 1196.12 100.17 0.92 MWD_M 26 2532.00 65.21 91.38 89.00 1928.79 1265.82 ":'212.50 1258.05 1275.87 99.59 1.05 MWD_M 27 2633.00 65.33 91.89 101.00 1971.05 1357.55 -215.12 1349.75 1366.79 99.06 0.47 MWD_M 28 2729.00 65.74 92.16 96.00 2010.80 1444.93 -218.21 1437.08 1453.55 98.63 0.50 MWD_M 29 2824.00 66.41 91.93 95.00 2049.33 1531.76 -221.31 1523.86 1539.85 98.26 0.74 MWD_M 30 2919.00 65.19 91.29 95.00 2088.27 1618.40 -223.74 1610.48 1625.94 97.91 1.42 MWD_M ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 16:37:10 Page 3 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 31 3014.00 65.58 91.54 95.00 2127.84 1704.76 -225.87 1696.82 1711.78 97.58 0.48 MWD_M 32 3109.00 64.92 92.13 95.00 2167.61 1791.03 -228.64 1783.04 1797.64 97.31 0.89 MWD_M 33 3204.00 65.54 92.03 95.00 2207.42 1877.29 -231.77 1869.25 1883.56 97.07 0.66 MWD_M 34 3299.00 65.86 90.88 95.00 2246.51 1963.85 -233.96 1955.80 1969.74 96.82 1.15 MWD_M 35 3394.00 65.23 91.70 95.00 2285.84 2050.31 -235.91 2042.25 2055.83 96.59 1.03 MWD_M 36 3490.00 65.65 91.47 96.00 2325.74 2137.62 -238.32 2129.53 2142.83 96.39 0.49 MWD_M 37 3534.54 65.53 91.52 44.54 2344.15 2178.17 -239.38 2170.08 2183.24 96.29 0.29 MWD_M ~ 38 3623.00 64.27 90.60 88.46 2381.67 2258.26 -240.87 2250.17 2263.02 96.11 1.71 MWD 39 3717.00 63.54 92.15 94.00 2423.02 2342.66 -242.89 2334.56 2347.16 95.94 1.67 MWD 40 3811.00 63.00 91.81 94.00 2465.30 2426.61 -245.79 2418.46 2430.92 95.80 0.66 MWD 41 3905.00 62.61 92.39 94.00 2508.26 2510.22 -248.85 2502.02 2514.36 95.68 0.69 MWD 42 3999.00 62.38 92.06 94.00 2551.67 2593.59 -252.09 2585.33 2597.59 95.57 0.40 MWD 43 4093.00 63.40 92.42 94.00 2594.51 2677.26 -255.36 2668.93 2681.12 95.47 1.14 MWD 44 4185.00 64.40 90.90 92.00 2634.99 2759.87 -257.75 2751.51 2763.56 95.35 1.84 MWD 45 4277.00 64.21 90.97 92.00 2674.87 2842.75 -259.10 2834.41 2846.22 95.22 0.22 MWD 46 4374.00 64.55 90.44 97.00 2716.82 2930.17 -260.18 2921.86 2933.42 95.09 0.60 MWD 47 4458.00 64.80 90.58 84.00 2752.75 3006.06 -260.86 2997.79 3009.11 94.97 0.33 MWD 48 4564.00 65.24 90.54 106.00 2797.51 3102.09 -261.79 3093.87 3104.92 94.84 0.42 MWD 49 4661.00 65.16 90.49 97.00 2838.20 3190.10 -262.59 3181.92 3192.73 94.72 0.09 MWD 50 4756.00 63.88 91.30 95.00 2879.07 3275.83 -263.92 3267.66 3278.30 94.62 1.55 MWD 51 4851.00 63.22 91.76 95.00 2921.38 3360.87 -266.19 3352.69 3363.24 94.54 0.82 MWD 3445.58 3437.38 94.47 0.41 --~ 52 4946.00 62.98 91.42 95.00 2964.36 -268.54 3447.85 MWD 53 5041.00 63.11 91.90 95.00 3007.43 3530.26 -271.00 3522.02 3532.43 94.40 0.47 MWD 54 5136.00 63.29 91.84 95.00 3050.26 3615.05 -273.76 3606.77 3617.14 94.34 0.20 MWD 55 5231.00 63.18 90.71 95.00 3093.04 3699.85 -275.65 3691.57 3701.85 94.27 1.07 MWD 56 5326.00 62.99 91.15 95.00 3136.05 3784.53 -277.03 3776.27 3786.41 94.20 0.46 MWD 57 5422.00 62.98 89.58 96.00 3179.65 3870.00 -277.57 3861.79 3871.75 94.11 1.46 MWD 58 5517.00 62.56 89.85 95.00 3223.12 3954.38 -277.15 3946.26 3955.98 94.02 0.51 MWD 59 5613.00 62.41 89.61 96.00 3267.47 4039.43 -276.75 4031.40 4040.88 93.93 0.27 MWD 60 5708.00 63.71 90.31 95.00 3310.51 4124.04 -276.69 4116.08 4125.37 93.85 1.52 MWD [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 16:37:10 Page 4 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) ( ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5802.00 63.97 90.42 94.00 3351.96 4208.36 -277.23 4200.45 4209.59 93.78 0.30 MWD 62 5898.00 63.78 90.64 96.00 3394.23 4294.51 -'-278.03 4286.64 4295.65 93.71 0.29 MWD 63 5993.00 63.95 90.19 95.00 3436.07 4379.74 -278.65 4371.93 4380.80 93.65 0.46 MWD 64 6088.00 63.80 90.40 95.00 3477.90 4464.98 -279.08 4457.22 4465.95 93.58 0.25 MWD 65 6184.00 64.04 90.71 96.00 3520.11 4551.16 -279.92 4543.44 4552.06 93.53 0.38 MWD 66 6279.00 64.24 90.69 95.00 3561.55 4636.61 -280.96 4628.92 4637.44 93.47 0.21 MWD 67 6374.00 64.63 89.96 95.00 3602.54 4722.25 -281.45 4714.62 4723.01 93.42 0.81 MWD "-'---' 68 6469.00 64.72 90.25 95.00 3643.18 4808.06 -281.61 4800.49 4808.74 93.36 0.29 MWD 69 6564.00 64.76 89.92 95.00 3683.72 4893.90 -281.73 4886.40 4894.52 93.30 0.32 MWD 70 6658.00 64.25 92.59 94.00 3724.18 4978.72 -283.59 4971.22 4979.30 93.26 2.62 MWD 71 6755.00 64.05 92.42 97.00 3766.48 5066.02 -287.40 5058.43 5066.59 93.25 0.26 MWD 72 6849.00 64.31 93.17 94.00 3807.42 5150.63 -291.53 5142.94 5151.20 93.24 0.77 MWD 73 6945.00 64.40 93.29 96.00 3848.97 5237.16 -296.41 5229.35 5237.74 93.24 0.15 MWD 74 7040.00 64.67 92.82 95.00 3889.81 5322.93 -300.98 5315.00 5323.51 93.24 0.53 MWD 75 7135.00 64.77 93.25 95.00 3930.38 5408.82 -305.53 5400.78 5409.42 93.24 0.42 MWD 76 7231.00 64.60 93.38 96.00 3971.43 5495.59 -310.54 5487.42 5496.20 93.24 0.22 MWD 77 7324.00 64.90 93.22 93.00 4011.10 5579.70 -315.39 5571.39 5580.31 93.24 0.36 MWD 78 7420.00 64.64 92.75 96.00 4052.02 5666.53 -319.91 5658.11 5667.15 93.24 0.52 MWD 79 7515.00 64.71 92.59 95.00 4092.66 5752.40 -323.91 5743.89 5753.02 93.23 0.17 MWD 80 7612.00 64.44 92.18 97.00 4134.30 5840.01 -327.55 5831.42 5840.61 93.21 0.47 MWD 81 7707.00 63.58 92.20 95.00 4175.93 5925.40 -330.82 5916.75 5925.99 93.20 0.91 MWD 7802.00 62.85 92.19 95.00 4218.75 6010.20 -334.07 6001.49 6010.78 93.19 0.77 MWD --- 82 83 7897.00 62.37 92.54 95.00 4262.45 6094.55 -337.55 6085.77 6095.13 93.17 0.60 MWD 84 7992.00 63.60 92.73 95.00 4305.60 6179.19 -341.44 61 70 . 31 6179.75 93.17 1.31 MWD 85 8087.00 63.21 92.59 95.00 4348.13 6264.13 -345.38 6255.17 6264.70 93.16 0.43 MWD 86 8182.00 63.21 92.29 95.00 4390.95 6348.94 -3 48 . 99 6339.90 6349.50 93.15 0.28 MWD 87 8277.00 63.12 91.98 95.00 4433.83 6433.70 -352.15 6424.61 6434.25 93.14 0.31 MWD 88 8373.00 62.96 91.99 96.00 4477.36 6519.27 -355.11 6510.12 6519.80 93.12 0.17 MWD 89 8468.00 62.80 91.86 95.00 4520.66 6603.82 -357.95 6594.63 6604.34 93.11 0.21 MWD 90 8563.00 62.76 91.44 95.00 4564.12 6688.29 -360.38 6679.07 6688.79 93.09 0.40 MWD [(c)2001 Anadrill IDEAL ID6_1C_08] [(c)2001 Anadrill IDEAL ID6_1C_08] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 16:37:10 Page 5 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8658.00 62.73 91.14 95.00 4607.62 6772.73 -362.29 6763.51 6773.20 93.07 0.28 MWD 92 8752.00 62.38 91.02 94.00 4650.95 6856.13 -363.86 6846.91 6856.57 93.04 0.39 MWD 93 8847.00 62.05 90.92 95.00 4695.23 6940.15 -365.28 6930.95 6940.57 93.02 0.36 MWD 94 8942.00 63.11 91.52 95.00 4738.98 7024.46 -367.08 7015.25 7024.85 93.00 1.25 MWD 95 9038.00 62.85 91.51 96.00 4782.59 7109.97 -369.34 7100.74 7110.34 92.98 0.27 MWD 96 9133.00 62.35 91.52 95.00 4826.31 7194.30 -371.57 7185.06 7194.66 92.96 0.53 MWD 97 9227.00 63.78 91.42 94.00 4868.89 7278.09 -373.72 7268.83 7278.43 92.94 1.52 MWD - "",-, 98 9323.00 63.55 91.41 96.00 4911.48 7364.12 -375.84 7354.84 7364.44 92.93 0.24 MWD 99 9418.00 62.88 91.44 95.00 4954.29 7448.91 -377.95 7439.62 7449.21 92.91 0.71 MWD 100 9513.00 64.42 91.34 95.00 4996.45 7534.02 -380.02 7524.72 7534.31 92.89 1.62 MWD 101 9608.00 63.78 91.16 95.00 5037.95 7619.46 -381.88 7610.16 7619.73 92.87 0.69 MWD 102 9703.00 63.00 90.97 95.00 5080.50 7704.38 -383.46 7695.08 7704.63 92.85 0.84 MWD 103 9798.00 62.76 91.33 95.00 5123.81 7788.91 -385.16 7779.62 7789.15 92.83 0.42 MWD 104 9893.00 62.80 91.52 95.00 5167.26 7873.38 -387.26 7864.07 7873.60 92.82 0.18 MWD 105 9986.00 62.59 92.04 93.00 5209.92 7956.01 -389.83 7946.67 7956.22 92.81 0.55 MWD 106 10083.00 63.74 91.28 97.00 5253.71 8042.56 -392.33 8033.18 8042.76 92.80 1.38 MWD 107 10181.00 63.37 91.29 98.00 5297.35 8130.29 -394.30 8120.91 8130.47 92.78 0.38 MWD 108 10276.00 64.25 91.74 95.00 5339.28 8215.52 -396.55 8206.12 8215.70 92.77 1.02 MWD 109 10371.00 63.98 91.16 95.00 5380.76 8300.98 -398.72 8291.56 8301.15 92.75 0.62 MWD 110 10467.00 66.01 91.89 96.00 5421.33 8387.96 -401.04 8378.53 8388.12 92.74 2.22 MWD 111 10561.00 65.88 91.33 94.00 5459.65 8473.79 -403.45 8464.33 8473.94 92.73 0.56 MWD 112 10656.00 65.74 90.81 95.00 5498.58 8560.43 -405.07 8550.97 8560.56 92.71 0.52 MWD ~' 113 10751.00 65.96 90.38 95.00 5537.44 8647.07 -405.97 8637.66 8647.19 92.69 0.47 MWD 114 10846.00 66.10 90.51 95.00 5576.04 8733.83 -406.64 8724.46 8733.93 92.67 0.19 MWD 115 10941.00 66.21 90.05 95.00 5614.44 8820.66 -407.06 8811.35 8820.75 92.65 0.46 MWD 116 11036.00 65.81 90.24 95.00 5653.07 8907.39 -407.28 8898.14 8907.46 92.62 0.46 MWD 117 11132.00 65.97 90.47 96.00 5692.28 8994.96 -407.83 8985.77 8995.02 92.60 0.27 MWD 118 11227.00 65.81 92.26 95.00 5731.09 9081.65 -409.89 9072.45 9081.70 92.59 1.73 MWD 119 11322.00 65.94 91.68 95.00 5769.92 9168.35 -412.87 9159.10 9168.40 92.58 0.57 MWD 120 11418.00 65.08 91.34 96.00 5809.72 9255.70 -415.17 9246.43 9255.75 92.57 0.95 MWD ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 16:37:10 Page 6 of 6 --- -------- ------ ------- ------ -------- -----_.:.....- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11513.00 64.09 91.58 95.00 5850.49 9341.50 -417.36 9332.21 9341.54 92.56 1.07 MWD 122 11608.00 63.52 91.79 95.00 5892.42 9426.73 -419.87 9417.42 9426.77 92.55 0.63 MWD 123 11704.00 63.23 91.02 96.00 5935.45 9512.54 -421.97 9503.21 9512.57 92.54 0.78 MWD 124 11800.00 64.91 91.58 96.00 5977.42 9598.85 -423.93 9589.52 9598.88 92.53 1.83 MWD 125 11894.00 65.40 90.75 94.00 6016.92 9684.13 -425.67 9674.80 9684.16 92.52 0.96 MWD 126 11990.00 66.18 90.24 96.00 6056.29 9771.64 -426.42 9762.35 9771.66 92.50 0.95 MWD 127 12084.00 65.65 89.66 94.00 6094.65 9857.38 -426.35 9848.17 9857.39 92.48 0.80 MWD - -- 128 12181.00 65.30 89.84 97.00 6134.91 9945.54 -425.96 9936.42 9945.54 92.45 0.40 MWD 129 12275.00 64.73 90.13 94.00 6174.62 10030.66 -425~94 10021.62 10030.67 92.43 0.67 MWD 130 12365.00 64.46 90.47 90.00 6213.23 10111.91 -426.36 10102.91 10111.91 92.42 0.45 MWD 131 12463.00 64.43 90.04 98.00 6255.50 10200.26 -426.76 10191.33 10200.26 92.40 0.40 MWD 132 12557.00 63.76 90.51 94.00 6296.57 10284.75 -427.16 10275.88 10284.75 92.38 0.84 MWD 133 12653.00 63.20 91.79 96.00 6339.44 10370.63 -428.88 10361.76 10370.63 92.37 1.33 MWD 134 12748.00 62.72 91.17 95.00 6382.62 10455.23 -431.07 10446.34 10455.23 92.36 0.77 MWD 135 12843.00 61.45 91.54 95.00 6427.10 10539.16 -433.05 10530.26 10539.17 92.35 1.38 MWD 136 12939.00 61.96 91.88 96.00 6472.60 10623.69 -435.58 10614.76 10623.69 92.35 0.62 MWD 137 13034.00 62.03 91.24 95.00 6517.21 10707.55 -437.86 10698.60 10707.56 92.34 0.60 MWD 138 13130.00 62.07 91.71 96.00 6562.21 10792.34 -440.04 10783.37 10792.35 92.34 0.43 MWD 139 13225.00 62.45 91.59 95.00 6606.42 10876.42 -442.46 10867.42 10876.42 92.33 0.42 MWD 140 13320.00 62.48 91.71 95.00 6650.34 10960.65 -444.89 10951.63 10960.66 92.33 0.12 MWD 141 13415.00 62.64 91.54 95.00 6694.12 11044.96 -447.28 11035.90 11044.96 92.32 0.23 MWD 142 13511.00 62.74 91.48 96.00 6738.17 11130.24 -449.53 11121.17 11130.25 92.31 0.12 MWD - 143 13606.00 63.12 91.58 95.00 6781.40 11214.83 -451.79 11205.74 11214.84 92.31 0.41 MWD 144 13701.00 62.95 91.51 95.00 6824.48 11299.49 ~454.07 112~0.38 11299.50 92.30 0.19 MWD 145 13797.00 63.93 91.96 96.00 6867.40 11385.35 -456.67 11376.20 11385.37 92.30 1.10 MWD 146 13890.00 64.80 91.49 93.00 6907.63 11469.19 ~459.19 11460.01 11469.21 92.29 1.04 MWD 147 13930.00 64.92 91.33 40.00 6924.63 11505.40 -46D.09 11496.21 11505.41 92.29 0.47 MWD 148 14003.00 64.92 91.33 73.00 6955.57 11571.50 -461.62 11562.31 11571.52 92.29 0.00 MWD Projected All survey type "MWD" is corrected using IIFR [(c)2001 Anadrill IDEAL ID6_1C_08] 6/18/2001 Sc~lußl'epgep NO. 1225 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine - '-";' Color Well Job# Log Description Date BL Sepia Prints CD CD1-14 ?t)J..o~ 21248 M10, ARC, D/N 05/09/01 1 CD1-14 21248 MD VISION RES. 05/09/01 1 1 CD1-14 21248 TVD VISION RES. 05/09/01 1 1 ,.-- ~./ "- W~ ~. , SIGNED: ~ ~ Á A.) DATE: RECEIVED JUN 22 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Alaska Oil & Gas ConS. Commiletori Anchorage 6/14/2001 SchlulI~el'gep NO. 1218 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine Color Well Job# Log Description Date BL Sepia Prints iD1-25 PRODUCTION PROFILE OS/28/01 1 1 - ~1-30 MEM PRODUCTION PROFILE OS/20/01 1 1 ". ~CD1-35 PRODUCTION PROFILE 05/18/01 1 1 (V) ~1-14PB1 21247 M10, ARC, D/N 04/09/01 9 ~1-14PB1 21247 MD VISION RES. 04/09/01 1 1 -.:..... ~1-14PB1 21247 TVD VISION RES. 04/09/01 1 1 -0 ~1-14PB1 21247 MD VISION DEN/NEUTRON 04/09/01 1 1 <i) CD1-14PB1 21247 TVD VISION DEN/NEUTRON 04/09/01 1 1 CD 1 ,- SIGN~~(~ _ DATE: Ht:Cl::tVED tUN 1 5 2001 Þ8Q0iI & GIS Cons. Commi8eion MchoI'age Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. a Ô[T- ~ fd a..O/-D5'l r- Scblumbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sh~rrie Well Job# Log Description Date CD1-33 CD1-14 INJECTION PROFILE USIT 05/13/01 04/27/01 21225 Sl~t'~ Ch~ .--/ 5/30/2001 NO. 1174 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine (Open Hole) BL Sepia Color Prints CD 1 1 1 RE ~EIVED DATE: JUN 0 1 2001 Alaska Oil & Gas Cons. Commission Please sign and return one c.opy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Tha~Nage ) MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: Well No CD1-14PH Date Dispatche I nstallation/Rig Doyon 19 Dispatched By: LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) d.Dl-D3i 2 Received By: ~ 6.. 000 pu- ) LWD Log Delivery V1.1, Dec '97 ) Rt('t1VED MAY ()2 2001 @¡ill g;, ~lfi'r§ri1:jì:á)g~; AOGCC 29-Apr-01 Nate rose Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 'r c2 0 ¡~03-S Casing Detail 95/8" Surface CasinQ vDI ~PHILLIPS Alaska, Inc. ìiJ A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 86 Doyon 19 RKB to LDS FMC Gen V Hanger 84 Jts 9-5/8" 40# L-80 MBTC Csg Davis Lynoh Float Collar 2 Jts 9-5/8" 40# L-80 MBTC Csg Davis Lynoh Float Shoe Jts 1 to 2 ¥Lf TD 12 1/4" Surface Hole RUN TOTAL 48 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54,56,58,60,62,64, 66,68,70,72,74,76,78,80,82,84. Last 4 joints stay out # 87 thru # 90. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -175 k On Wt -135 k Block Wt - 70 SC¡\~NEtJ \FEB 2 ~ 2004· dO/-03[[ Well: Date: LENGTH 36.80 2.21 3463.04 1.60 81.08 1.77 3596.00 Supervisor: Don Mickey CD1-14 2/28/01 DEPTH TOPS 36.80 39.01 3502.05 3503.65 3584.73 3586.50 ) Phi II ips Alaska Drilling I Well Name: CD1·14 Rig Name: Doyon 19 Casing Size 95/8" Centralizers Comments: Mud Comments: Wash 0 Comments: Vlscoslfled wI nut plug Spacer 0 Comments: Lead Cement 0 Comments: Tall Cement 0 Comments: Displacement 0 Comments; Calculated top of cement : Surface Hole Diameter: 121/4" Angle thru KRU: Report Date: 0310312001 AFC No.: 998D02 Shoe Depth: 3586 Ct:¡entinJ:l Details I LC Depth: 3502 Report Number: 1 Field: Alpine % washout: State type used. intervals covered and spacing 48 bow spring - 1 per Jt for first 12 Its. ,then 1 every other Jt from #14 to # 84 Weight: 9.9 PV(prlor cond): 20 Gels before: 29,72.91 Gels after: 4,25,32 Type: Water Type: ARCO 645 Type: ASIII Mix wtr temp: 70 PV(after cond): 21 Total Volume Circulated: 1080 bbls Volume: 40 bbls Volume: 50 bbls No. of Sacks: 566 YP(prior cond): 36 Weight: 10.7 ppg Type: G Mix wtr temp: 70 Additives: G wI 30 % D053, 0.6% D046, 1.5% D079, 1.5% 5001, 50% D124, 9% 6WOW D44 Weight: 15.8 ppg Additives: G wI 0.2% D046, 0.3% D065, 1 % S001 Rate(before tail at shoe): 8 bblsl mln Reciprocation length: 20' Theoretical Displacement: 265.5 CP: Date:03l01/2oo1 Time:0930 hrs. Remarks:Full returns through out job· 95.5 bbls cmt returns to surface I Cement Company: Dowell I Rig Contractor: DOYON No. of Sacks: 237 Rate(tail around shoe): 8 bblsl mln Reciprocation speed: Actual Displacement: 265.5 Bumped plug: Yes Floats held: Yes Approved By: Don Mickey YP(after cond): 16 Weight: 8.3 ppg Weight: 10.5 ppg Yield: 4.44 Yield: 1.17 Str. Wt. Up: 175 Str. Wt. Down: 135 Str, Wt. in mud: ) Phillips Alaska Drilling N=C No. Date Rpt No 998D02 03101/2001 5 Well: CD1-14 Rig Accept - hrs 0212612001 05:00:00 AM Days Since Accept/Est: 3.8 /4.5 Depth (MDfTVD) 3596/2370 Prev Depth MD: 3596 Cum Cost $ 584795 Next Csg: Contractor. DOYON Rig Name: Doyon 19 Operation At 0600: Testing 9 5/8" csg Upcoming Operations: Freeze protect well & release rig MUD DATA MUD TYPE SPUD WEIGHT 9.9ppg VISCOSITY 63sqc PVNP 21/16 GELS 4/25/32 APIWl HTHP WL ml130 mln SOLIDS % HOLE VOLUME 271 bbJ MBT ph LGS % PIT VOL o DAILY MUD $3958 TOTAL MUD $12065 COMPANY MI BHA DESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: "rIME I END 12:00 AM 03:00 AM 03:00 AM 06:00 AM 06:30 AM 07:00 AM Dally Cost $ 209121 Last Csg: 9 5/8" @ 3586' DRilLING DATA BIT DATA DEPTH BIT NO. BIT NO. ROTWT SIZE SIZE PUWT MAKE MAKE SOWT TYPE TYPE AVG DRAG SERIAL NO SERIAL NO MAX DRAG DEPTH OUT DEPTH OUT TRQ BTM DEPTH IN DEPTH IN TRQ OFF FOOTAGE FOOTAGE PUMP PRES ADT/AST ADT/AST III / / PUMP NO WOB2 WOB2 11211 LINER SZ RPM 1 RPM 1 5.51611 SPM 1 TFA TFA III GPM2 JETS JETS III 11111 IIIII SPS 1 BIT COST BIT COST III SPP 1 DULL DULL III III III MUDWT GRADE GRADE 9.7111 III III OD 10 4.218 EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 02128/2001 INJECTION INJECTION WELL CD1·31 SOURCE WELL CD1-14 RATE (bpm) 4 PRESSURE (psi) 1110 INJECTION FLUIDS Water Base Muds 1685 Fresh Water 150 Diesel 115 Other 643 o TOTAL VOL (bbl) 2593 TOT FOR WELL (bbl) 6162 ) Daily Drilling Report Rig Relasa - hrs: Progress: 0 Est Cost To Date $1000000 Shoe Test: DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 0212312001 0212612001 LAST H2S DRILL 0211612001 LAST CONFINED SPACE LAST FIRE DRILL 02128/2001 LAST SPILL DRILL 02119/2001 FUEL & WATER FUEL USED 1956 5" 98.9 HOURS 3.00 OPS CODE RUN_CSG HOLE SECT SURF DRill WATER USED - BBLS POTABLE WATER USED - BBLS 180 90 06:00 AM 06:30 AM 07:00 AM 09:30 AM CIRC CMT _CSG OTHER CMT _CSG SURF SURF SURF SURF WEATHER & PERS()NNEL,DATA TEMP of -12 3.00 0.50 0.50 2.50 WIND SPEED 10 WIND DIRECTION 50° CHILL FACTOR of -35.67 PHilLIPS PERSONNEL CONTRACTOR PERSONNEL 27 MISC PERSONNEL SERVICE PERSONNEL TOTAL 15 49 WEIGHT 19.5 QRILLPIPE DATA GRADE CONNEOTION G105 4·1/2" I.F. LENGTH 1 PHASE OPS Making Hole Making Hole Making Hole Making Hole Making Hole 09:30 AM 12:00 PM 2.50 OTHER SURF Making Hole 12:00 PM 09:30 PM 9.50 OTHER SURF Other 09:30 PM 11:30 PM 2.00 NU_NO SURF Other 11:n0 PM 12:00 AM 0.50 NU NO SURF Other )ai y Drilling Report: CD1-14 03/01/2001 24.00 CLASS 2 I OPERATIONS FROM 0000 - 0000 Continue running 9 5/8" 40# L·80 csg - ran 86 Its. total landed on mandrel w/ flò':r shoe @ 3586' float collar @ 3502' Clrc and condition for emt Job Rig down fill up tool - Rig up cmt head Held PJSM Cement 9 5/8" csg - pumped 40 bbls. Vis water w/nut plug - test lines to 2500 psi - drop btm plug - pump 50 bbls Arco spacer @ 10.5 ppg. mix and pumped 448 bbls 10.7 ppg lead slurry and 49.5 bbls 15.8 ppg tall slurry -( Note had wash out on cmt line In mud pits wI 365 bbls lead pumped· shut down and changed lines - resume pumping no problems· Observed nut plug @ 440 bbls lead pumped) drop top plug w/20 bbls water fl Dowell - switch to rig pumps and displace wI mud 245 bbls - bumped plug - floats held - CIP @ 0930hrs. 95 bbls cmt returns to surface Rig down cmt head - landing Jt. - wash out riser and 20" dlverter Lay down 32 stds. 5" DP - 9 stds. HWDP - 40 stds 3 1/2" DP from derrick Nipple down dlverter, riser, flow line Install FMC Unlhead Page 3 TEST and FORMATION INTEGRITY TEST Date: Supervisor: Don Mickey Initial Casing Shoe Test Formation Adequacy for Annular Injection IJ Deep Test Open Hole Adequacy for Higher Mud Weight Size and Hole Depth: Length of Open + Mud Weight ::::: 9.6 ppg Ri unit used FlUid Pumped '" Fluid Bled Back - NO #1 Pump output", 0.08$8 bps PHILLIPS A Subsidiary of PHiLLiPS MINUTES FOR MINUTES FOR CSG TEST "'~---------- ~H.U""H"""" CASING T'L~ r and FORMATION INTEGRITY TEST , --.-.-'" Well Name: CD1-14 4/26/01 Date: Supervisor: D.Mickey Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 40# L-80 BTMC X 7" 26# L-80 BTMC Casing Setting Depth: Toe Hole Depth: 12846 6,436' TVD 3,586' TMD 2,365' TVD Mud Weight: 10.2 ppg Length of Open Hole Section: 9,260' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 601 psi + 10.2 ppg 0.052 x 2,365' EMW for open hole section = 15.1 ppg Used cement unit- Rig pump used Pump output = bbls pumped Fluid Pumped = 19.0 bbls Fluid Bled Back = 0.0 bbls yes -#2 800 psi 700 psi I ! 1IIIII IIIIII11 ÌÌ'1~ 111111II TIMEUNF~ - _ _I OÑ'EMINWE TÍCKS~- 600 psi /1 ~ LEAK-OFF TEST ~CASING TEST ---+-- LOT SHUT IN TIME -k- CASING TEST SHUT IN TIME . -+-TIME LINE 5CO psi w 0: ::> ~ 400 pSi w 0: 0.. 300 psi 1 00 psi o psi ~'Å o 10 20 30 BARRELS 40 so NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA (;fJ MINUTES FOR LOT BBLS PRESSURE [~~~~~~~~~~~~~~~I~~~~~~~~~=:~J~~--~:P-~~~:~::I ! ! 1.0 ¡ 121 psi ¡ I----------------i--------~------------:---t I : 2.0 I 162 pSI : :----------------i---------------of----------------f : : 3.0 : 177 psi : I----------------~---------------.----------------. : : 4.0 : 192 psi I :----------------~--------------+----------------. ! ! 5.0 ! 207 psi ! .----------------,,--------------.,-----------------, ¡ ¡ 6.0 ¡ 232 psi ¡ ¡--------------I------¡:Õ----r--25S-ps¡---¡ ¡~:~~~~:~~~~::~~i:::~ll~1 ! ! 12.0 ! 399 psi ! L_______________.I_______________.J._______________, ¡ i 13.0 ¡ 439 psi ! I---------------i------------~---------------t : : 14.0 : 459 psi : :---------------i--------------~-----------------. : : 15.0 : 495 psi : :---------------i---------------of---------------f ~--------------J-----!~:~----.1_---~-º~-J.?-~!---t ¡ ¡ 16.0 ! 515 psi ! f---------------r--1-6~Š----r-Š3õ-ps¡--1 f---------------r--T7~õ----r-545-pš¡--1 ....---------------.,---------------"1----------------1 ! ! 17.5 ¡ 570 psi ! r--------------T----1-ã:õ----y---šõ1--p-š¡-1 r--------------l-----fis----r-šõ1--ps¡---¡ r-------------T - - -.¡ 9:Õ- - - T - - 6Õ-1- pši - - ¡ I I ' , : SHUT IN TIME I SHUT IN PRESSURE '--------------_.&_------------------------------ ! 0.0 min ¡ ! 601 psi ! I--------------i---------------+----------------t : 1.0min I : 560 psi : ¡---------:----i------------""i------------:---t I 2.0 mln I I 555 pSI I :--------------~---------------.---------------. : 3.0 min : : 545 psi : :---------------~---------------.-----------------. ! 4.0 min ! ! 540 psi ¡ .-----------;----1---------------y------------:---r : 5.0 mln : : 540 pSI : r--------------~---------------.,._-------------t ¡ 6.0 mín ¡ ¡ 535 psi ¡ ~~~2~~~~~~~=~~~~~~~~~~~~~~~~¡~~§~~~~~~~~~ ~--~:Q-~~~--~---------------+---~~º--J.?-~~---i : 9.0 mtn : : 530 pSI : [~~iº~º=~16~~1~~=~~~~~~~~~~~I=~~~~~~!~~~1 8 ' . ~ PHilliPS Alaslfa, Inc. A Slbsidiary of PHIlliPS PETROLELM CC+.1PANY -.. . CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r--------------l---õ-st-k'š--l-----ö-p-Š¡----l :----------------f---- ----------- t-- ---------- ----1 , I I I ~---------------+---- ---- -------+---------- ------1 I I I I !---------------- t- -------- ------t--------- --------1 , I I I ~--------------+- ---- --- - --- ---+-----------------i I I I I ~-- -------------+-------- - --- ---+----------------~ I I I , I I I I :------------- ---~---- -- -- --- ----~----------------4 , I I I I I I J , I , , .----------------7---------------7----------------.,. : : : ;~.- I I I I ,..---------------1"-------------- -1"-- - -------- -----...... I I I I , I I I I I I I ~----- -- --- ---- -+ -------- --- --- -+ --- --- -- ---------t I I . I I I I I I I I I ... ____________ __+__ __ _____ ______+__ __ __ ___ __... _ ----t r I I f I I r I I I . I 11-_____________ __"'_________ -_____..._____ -- --...- ------' I I . I I I r I I I , I :---------- ------t-------- ---- ---t----------- ------: · I . . · I . I :-------- -- ------t-- ---- - - - ------t----------------i , I . I ~-----------u--t---- --- ----- ---t-----------------I I I I I , I , I :----------------t---------------t----------------; I I I I ~-------- -------+ --- ----- -------+------ ----------1 , . , I ~---------------+---------------f--------------~ I I I I I I I I :----------------~--------------- ~---- - -- -- --------:, I , , I · I I . I I I I ,...------------ ---T--- ----------- - 7 -- -- -------- ----r I I r I , I r I I I I I i SHUT IN TIME ¡ SHUT IN PRESSURE 1---------------+----- -- -- ------ .,.---------- -------, ¡ 0.0 min ! ¡ 0 psi ¡ ...--------------....------ -- ----- --+ --- -------------.... ¡ 1.0 min ! ! ¡ r-_______________... ______ _-- -_____...___ _____________-' i 2.0min j ¡ ¡ ~----------~----t-------- - ------t--------------i : 3.0mln I : :~, :----------~----t---- ------- ----t---- ------------1 : 4.0 mln I : : :-----------:-----t---- ----- - -----t--- ------ -------; : 5.0 mln : : : :----------:-----t---------------t -- --------- -- ---; : 6.0 mln : I : }----------------t --- -- ---- - -----t-------------- ---I : 7.0min : : : :----------------f -- -- --- _u -- ---f--- ------------ --I ! 8.0min ! ¡ ¡ ,-------------- -,.---------------7--------- -- --- ---, ! 9.0min ! ! ¡ .---------------1' --- ------- -----7--------- --------, ¡ 10.0 min ! ¡ ¡ .---------------- f'---------------f'-- - - - ----- -------r ! 15.0 min ! ! ! ~---------------f'----------- ----+ -- --------------.., ¡ 20.0 min i i ¡ 1----------------+------ --- -- --- -. ---- ----- - -- - ---.... ! 25.0 min ! ! ¡ 1-_____ _____ _____...__________ ___ __4__ ___ __ -- _ ___ ---.. i 30.0 min ¡ i i ....____________ _ _ _... _ _________ __ ___ .a._______________....& NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY · . ( ¡¡PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY } t Number Num of Jts ts 3 to 343 341 Jts Jts 1 to 2 2 Jts ') Casing Detail 7" Intermediate CasinQ ( COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LOS FMC 1111 X 711 Hanger 711 26# L-80 STCM Csg 711 Davis Lynch Float Collar 711 26# L -80 STCM Csg 711 Davis Lynch Float Shoe TO 8 1/211 hole 14090' 1 SB centralizer per jt #1 - #20 1 SB centralizer every other jt #257- #341 Total - 63 centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wt -425+k Dn Wt - 75k Well: Date: LENGTH 34.33 1.30 13952.85 1.53 81.35 1.70 Supervisor: Oavid P. Burley CD1-14 4/24/01 DEPTH TOPS 34.33 35.63 13988.48 13990.01 14071 .36 14073.06 ( Phillips Alaska Drilling . . I Well Name: Rig Name: CD1-14 Doyon 19 Report Date: /;FC No.: Casing Size 7" Hole Diameter. 8.5+ Angle thru KRU: Centralizers Comments: 0412412001 998D02 ( Cementing Details I Report Number: Field: 31 Alpine Shoe Depth: 14073' LC Depth: 13988' % washout: State type used, intervals covered and spacing Ran 8-318" x 7" stalght balcle posltve stand off centralizers 1 per Joint on '1-20, every other Joint #257 - 341' (63 Total). Mud Comments: Weight: 10.2 PV(prior con d): 10 Gels before: 618111 Gels after. 618111 Wash 0 Comments: Spacer 0 Comments: Type: ARCO Wash Type: ARCO 845 Lead Cement 0 Comments: Type: Mix wtr temp: Additives: Tall Cement 0 Comments: Type: G Mix wtr temp: 70 PV(after cond): 10 YP(prior cond): 17 YP(after cond): 17 Total Volume Circulated: 1785 bbls Volume: Weight: 8.4 20 Volume: 50 Weight: 12.5 No. of Sacks: Weight: Yield: No, of Sacks: 235 Weight: 15.8 Yield: 1.15 ,Displacement 0 èomments: Rate(before tail at shoe): 7.1 Additives: 0.2% D046, 0.25% D065, 0.25% D800, 0.18% D167. Str, Wt. Up: 475+ CP: Date:4-25-o1 Time:0908 hrs Remarks:Pushed casing last 4 Joints to bottom. Staged up pumps to 6 bpm over first 250 bbls pumped, encountered 1 bpm losses at 6 bpm. Reduced rate to 5 bpm whh full returns and pumped 40 bbl pili with 4.0 ppb of MI Fine LCM. Circulated and conditioned mud, staged pumps up to 8.0 bpm after 20 bbls of pili around shoe with full returns. Had loss of pump pressure last 8 bbls of displacement, pumped 1.5 bbls over calculated displacement, did not bump plug. Observed annulus, standing full to flowline. Reciprocation length: o Theoretical Displacement: 535.5 Calculated top of cement: 12846' W/40% EXCESS Cement Company: Dowell Rig Contractor: DOYON Rate(tall around shoe): 7.1 Reciprocation speed: o Str. Wt. Down: 75 Actual Displacement: 537 Str. Wt. in mud: Bumped plug: NO Floats held: YES Approved By: David P. Burley f Phillips Alaska Drilling !<EC No. ggaD02 ( ( Daily Drilling Report Date 0412412001 RptNo 31 Rig Accept - hrs Days Since AcceptlEst: 28.1 /16 04101/2001 02:30:00 PM Rig Relsse - hrs: Well: CD1-14 Contractor. DOYON Rig Name: Doyon 19 Depth (MDITVD) Daily Cost $ 284178 last Csg: 9 5/8" @ 3586' 14090/6855 Prev Depth MD: 14090 Cum Cost $ 4343993.52 Next Csg: 7" @ 14,073' :)peration At 0600: Clrc and cond mud for cementing. Jpco~ing Operations: Cement 7" casing, Install packott, LD 5" drill pipe. MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO, LSND 6 WEIGHT ROT WT SIZE 10.2ppg 8.5 VISCOSITY PUWT MAKE 49sqc STC PVNP SOWT TYPE 10/17 FHO GELS AVG DRAG SERIAL NO 6/8/11 PP8406SI1 APIWl MAX DRAG DEPTH OUT 2.6 14090 HTHP WL TRO BTM DEPTH IN 9.5m1130 mln 14090 SOLIDS TRO OFF FOOTAGE 9.5% 0 HOLE VOLUME PUMP PRES ADT/AST 944bbl III / MBT PUMP NO WOB2 17.5 11211 2-5 ph LINER SZ RPM 1 9.5 5.51611 70 - 134 LGS SPM 1 TFA 4.9% III OPEN PIT VOL GPM2 JETS 450 III 11111 DAILY MUD SPS 1 BIT COST $6816 30 I 40 I 30 140 TOTAL MUD SPP 1 DULL $532128 III 11NOIA COMPANY MUD WT GRADE MI III X III NO I TD a~~J;j~~CFtIPTON BHA NO OD BHA LENGTH 5" DATE LAST INSPECTED: HOURS ON JARS: TIME I END HOURS I OPS COPE 12:00 AM 01 :30 AM 1.50 TRIP_OUT 01:30 AM 03:30 AM 2.00 TRIP _OUT 03:30 AM 04:00 AM 0.50 BHA 04:00 AM 05:00 AM U>O RIGS 05:00 AM 07:45 AM 2.75 RUN_CSG 07:45 AM 12:00 PM 4.25 RUN_CSG 12:00 PM 12:30 PM 0.50 CIRC 12:30 PM 04:30 PM 4.00 RUN_CSG 04:30 PM 05:30 PM 1.00 CIRC 05:30 PM 09:00 PM 3.50 RUN_CSG 09:00 PM 10:15 PM 1.2f CIRC ~ally Drilling Report: CD 1- 4 04/24/2001 SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS IIIII BIT COST DULL III GRADE III ID 4.218 WEIGHT 19.5 HOLE SECT I PHASE OPS S1P1 Trip Out S1P1 Trip Out S1P1 Trip Out S1P1 Other S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Casing and Progress: 0 Est Cost To Date $ 2924511 Shoe Test: 16.1 ppg EMW EH&S ACCIDENT (non-spill) N DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 0411912001 04117/2001 LAST H2S DRILL EMPLOYER LAST FIRE DRILL 04117/2001 LAST SPILL DRILL 04119/2001 SPILL N LAST CONFINED SPACE TYPE FUEL & WATER VOLUME (gallons) FUEL USED 2263 LAST SAFETY MTG 0412412001 DRILL WATER USED· BBlS . POTABLE WATER USED - BBLS 70 95 INJ.ECTION INJECTION WELL CD1-19 SOURCE WELL CD1-14 RATE (bpm) WEATHEÀ& PE.RSONNEL DATA TEMP of -7 WIND SPEED 4 PRESSURE (psi) WIND DIRECTION 350° INJECTION FLUIDS CHILL FACTOR of -7.00 o o PHILLIPS PERSONNEL o o CONTRACTOR PERSONNEL 25 o TOTAL VOL (bbl) o TOT FOR WELL (bbl) SERVICE PERSONNEL MISC PERSONNEL 12 TOTAL 43 DRIÜ.PIPEDATA GRAPE . CONNECTION G105 4-1/2"I.F. CLASS 2 LENG'r:H OPERATIONS FROM 0000 - 0000 POH from 5586' to shoe, backreamed tight spot @ 5470', monitor well. POH to BHA. Stand back BHA, LD tools. Service Top Drive and Blocks, adjust brakes on drawworks. AU to run 7" casing, held PJSM. Aun casing to 3526'. Stage pumps up and clrc full casing volume @ 10 bpm 880 psI. Reciprocated pipe PUW 145k· SOW 115k. Aun casing to 7166'. Stage pumps up to 8 bpm - 710 psi and CBU. Reciprocate pipe PUW 220k - SOW 120k. Run casing to 10653'. Stage pumps up to 8 bpm - 840 psi and CBU. Reciprocated Page 4 (0:15 PM 12:00 AM 1.75 24.00 RUN_CSG Dally Drilling Report: CD 1-14 04/24/2001 ( S1P1 Cementing Casing and Cementing pipe PUW 300K . SOW 120K( Run casing to 12527' @ midnight. .. Chuck Scheve (AOGCC) deferred BOP test to run casing. Supervisor: DAVID BURLEY Page 5 ( Phillips Alaska Drilling AFC No. 998D02 Date 0412512001 Rpt No 32 Rig Accept· hrs Days Since AccepUEst: 29.1/17 0410112001 02:30:00 PM Rig Relase - hrs: Well: CD1-14 Contractor. DOYON Rig Name: Doyon 19 Depth (MDfTVD) Daily Cost $ 141851 last Csg: 7" 0 14,073' 14090/6855 Prev Depth MD: 14090 Cum Cost $ 4485844.52 Next Csg: 4 1/2" completion Progress: 0 Est Cost To Date $ 3000ooo Shoe Test: 16.1 ppg EMW :Jperation At 0600: MIU 6 1/8" bit & 7" csg scraper assembly Jpcoming Operations: RIH w/7" csg scraper - Picking up 3 112" drill pipe MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO. LSND WEIGHT ROTWT SIZE 10.2ppg VISCOSITY PUWT MAKE 47sqc PVNP SOWT TYPE 11/18 GELS AVG DRAG SERIAL NO 6/9/11 APIWl MAX DRAG DEPTH OUT 2.4 HTHP Wl TRQ BTM DEPTH IN 9.4ml/30 min SOLIDS TRQ OFF FOOTAGE 9.5% HOLE VOLUME PUMP PRES ADT/AST 817bbl III / MBT PUMP NO WOB2 17.5 11211 ph LINER SZ RPM 1 9.1 5.51611 lGS SPM 1 TFA 4.9% III PIT VOL GPM2 JETS 240 III 11111 DAilY MUD SPS 1 BIT COST $3742 30 140 I 30 140 TOTAL MUD SPP 1 DUll $535869 III III COMPANY MUD WT GRADE MI III III ~8A:öEscRIPTION SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST / WOB2 RPM 1 TFA JETS 11111 BIT COST DUll III GRADE III BHA NO BHA lENGTH DATE LAST INSPECTED: HOURS ON JARS: TIME I END 12:00 AM 02:00 AM OD 10 4.218 WEIGHT 19.5 5" HOURS I OPS CODe HOLE SECT PHASE OPS 2.00 RUN_CSG S1P1 Casing and Cementing 5.00 CIRC S1P1 Casing and Cementing 02:00 AM 07:00 AM 07:00 AM 09:30 AM 2.50 CEMENT S1P1 Casing and Cementing S1P1 Casing and Cementing S1P1 Making Hole S1P1 Making Hole S1P1 MakIng Hole S1P1 Making Hole 09:30 AM 10:30 AM 1.00 CASG 10:30 AM 12:00 PM 1.50 OTHER 12:00 PM 01:00 PM 1.00 BHA 01 :00 PM 01 :30 PM 0.50 RIGS 01:30 PM 12:00 AM 10.50 OTHER Jolly Drilling Report: CCì1JM 04/25/2001 (' Daily Drilling Report EH&S ACCIDENT (non-spill) N [)RILL$lBOP DATA LAST BOPIDIVERT LAST BOP/DRill TST 0411912001 0411712001 LAST H2S DRill EMPLOYER LAST FIRE DRill 0412512001 LAST SPilL DRill 0412512001 SPill N LAST CONFINED SPACE TYPE FU.I::L & WATER VOLUME (gallons) FUEL USED 1930 LAST SAFETY MTG 0412412001 DRill WATER USED - BBlS POTABLE WATER USED· BBlS 450 90 IN~ECTION INJECTION WEll CD1-19 SOURCE WEll CD1·14 RATE (bpm) WEATHEfl& ~ERSQNNI$ÞPATA TEMP OF ·11 WIND SPEED 9 PRESSURE (psi) WIND DIRECTION 250° INJECTION FLUIDS CHill FACTOR OF -31.50 o o PHilLIPS PERSONNEL 2 o o CONTRACTOR PERSONNEL 28 o TOTAL VOL (bbl) o TOT FOR WEll (bbl) SERVICE PERSONNEL MISC PERSONNEL 12 TOTAL 47 DRlllPIPE DATA GRAD~ CONNECTION. G105 4-1/2" I.F. CLASS 2 l.EN~TH OPERATIONS FRbM 0000 . 0000 Continue running 7" csg to 14,073'· FC @ 13,988' (343 Its) had to push last 4 Its. to btm. Staged pumps up to 6 bpm - hole taking fluid @ 1 bpm- slowed pumps to 5 bpm w/ full returns - pumped 40 bbls LCM pili· staged pumps up to 8 bpm w/20 bbls pili out shoe had full returns @ 8 bpm PJSM . Cement 7" csg w/ 48 bbls slurry @ 15.8 ppg - Displaced w/30 bbls fresh water & 507 bbls 10.2 ppg mud 1.5 bbls over calc. displacement - didn't bump plug· floats held - CIP @ 09:08 hrs.- lost pump pressure last 8 bbls of displacement· observed annulus standing full @ flow line Tear out cmt head & lay down landing It. Pull wear bushing - Install 7" pack-off & test to 5000 psi - Install wear bushing PJSM - lay down 8 1/2" BHA Service pipe skate Lay down 5" drill pipe Page 1 ~..... c..J....t.c..~,)( I Phillips Alaska Drilling (' --.- .s E ï""1"'" I ^¿ ,;. -+ -pC" c¡ ~ ,'J ~.. ... AFC No, 998002 Well: CD1-14 Contractor. DOYON Rig Name: Doyon 19 Date 0412612001 RptNo 33 Rig Accept· hrs Days Since AccepVEst: 30.1/17.5 04101/2001 02:30:00 PM Depth (MDfTVD) Daily Cost $101279 Last Csg: 7" @ 14,073' 14090/6855 Prev Depth MD: 14090 Cum Cost $ 4587123.52 Next Csg: 4 1/2" completion ::>peration At 0600: Trip out wI bit & csg scraper ~~~Ing Operations: Run CBL - Test BOPE MUD DATA DRILLING DATA MUD TYPE DEPTH BIT NO, LSND 7 WEIGHT 10.2ppg VISCOSITY 58sqc PVIYP 11/16 GELS 6/10/14 APIWL 2.8 HTHP WL 9.6m1130 min SOLIDS 9.5% HOLE VOLUME 602bbl MBT 17.5 ph 9.0 LGS 4.9% PIT VOL 210 DAILY MUD $1254 TOTAL MUD $537124 COMPANY MI ·'ft.;ì·~;D~SÇFtIÞTlqN . BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: '. .·;1'IM~· I END 12:00 AM 02:30 AM 02:30 AM 04:00 AM 04:00 AM 05:00 AM 05:00 AM 06:00 AM 06:00 AM 05:30 PM 05:30 PM 06:30 PM 06:30 PM 11 :00 PM 11:00 PM 12:00 AM BIT DATA BIT NO. EH&S ~T (non-spill) ~ ~"--') EMPLOYER ROTWT SIZE 61/8" PUWT MAKE HTC SOWT TYPE J4 AVG DRAG SERIAL NO L857E MAX DRAG DEPTH OUT 13939 TRO BTM DEPTH IN TRO OFF FOOTAGE 13939 PUMP PRES ADT/AST III I PUMP NO WOB2 '1211 LINER SZ RPM 1 5.51611 SPM 1 TFA III GPM2 JETS III 11111 SPS 1 BIT COST 30 140 I 30 I 40 SPP 1 DULL III III MUD WT GRADE III III SIZE MAKE SPILL N TYPE TYPE SERIAL NO VOLUME (gallons) DEPTH OUT LAST SAFETY MTG 0412412001 DEPTH IN FOOTAGE 1t)l4ECTION INJECTION WELL CD1-19 SOURCE WELL CD1-14 RATE (bpm) ADT/AST I WOB2 RPM 1 PRESSURE (psi) TFA INJECTION FLUIDS JETS IIII1 BIT COST ('cr r 7':;' :? j (.' (: .. S ¡'V { :.,' 0:-(. ',' ...\~ Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ 3000ooo Shoe Test: 16.1 ppg EMW \ DRILLSfBOP DATA LAST BOPIDIVERT LAST BOPIDRILL TST 04119/2001 04117/2001 LAST H2S DRILL LAST CONFINED SPACE LAST FIRE DRILL 0412512001 LAST SPILL DRILL 0412512001 FUEL & WATER FUEL USED 2265 DRILL WATER USED - BBLS POTABLE WATER USED· BBLS 710 90 WÊÄTHER& flER$OfiiN!;;L DATA TEMP of WIND SPEED 5 WIND DIRECTION 350° CHILL FACTOR of -3.55 PHILLIPS PERSONNEL CONTRACTOR PERSONNEL 25 DULL III GRADE III o TOTAL VOL (bbl) o TOT FOR WELL (bbl) SERVICE PERSONNEL TOTAL . þlt, csg scraper, Junk sub, Junk sub, bit sub, 3 NM Compr Srv DP, 1 HWDP, lars, 4 HWDP . ORILl.pjFiE[)ATA· GRADE CONlIgCilQN G105 4·1/2" I.F. 9 288.80 OD ID 4.218 WEIGHT. 19.5 5" MISC PERSONNEL 5 13 44 CLA$$ 2 LENGTH HOURS I OPS CODE HOLE SECT I PHASE OPS OP'ERATIONS FROM 0000·0000 2.50 OTHER S1P1 Making Hole Continue lay down 5" drill pipe 1.50 BOPE S1P1 Making Hole Change top pipe rams to 3 1/2" X 6" - Change saver sub In top drive 1.00 BOPE S1P1 Making Hole Body test BOPS to 5000 psi ~ 1.00 BHA S1P1 Making Hole MIU 6 1/8" bit & 7" csg scraper assembly 11.50 TRIP IN S1P1 Making Hole RIH wI bit & scraper - picking up 3 1/2" drill pipe fl pipe shed to 8883' 1.00 OTHER S1P1 Making Hole Pull & std back 15 stds 31/2" S grade pipe In derrick - run In hole w/10 stds 31/2" grade G pipe fl derrick 4.50 TRIP IN S1P1 Making Hole Continue RIH wI bit & scraper - picking up 3 1/2" drill pipe fl pipe shed to 13,654' 1.00 RIGS S1P1 Making Hole Cut & slip 60' drill line 24.00 ....-.. ~) Il ~?~ c.þ Ç7(t ,,,.,,~ ; (! S .- '2./1 IJ 1._'. I If" I . . SupeNisor: [JÕÑMICKEY re D'! /P(¡; I ~ 1 S~ '^-Il (( Dally Drilling Report: CD 1-14 04/26/2001 ìùt' 01 ril(J/INf -'¥ !?' ,~? -IS' .JI'V\.{)' -.,,'.,.,......,,'~._...-.....-" 7ts{" ¿:.¡: yç:.' é 131f)~ ( ;/~ Page 1 /.' ~) \--P: Z, "51fj{ ¿. ~/ --..--- Phillips Alaska Drilling AFC No. 998D02 Date 0412712001 RptNo 34 Rig Accept - h~ Days Since Accept/Est: 31.1 / 18.5 0410112001 02:30:00 PM Well: CD1-14 Contractor. DOYON Rig Name: Doyon 19 Depth (MD/TVD) Daily Cost $ 224934 Last Csg: 7" @ 14,073' ( 14090/6855 Prev Depth MD: 14090 Cum Cost $ 4812057.52 Next Csg: 4112" completion :>peration At 0600: RIH w/ 6 1/8" drilling assembly Jpcoming Operations: Test 7" csg - clo shoe track - perform FIT/LOT - Drill 6 1/8" hole MUD DATA DRILLING DATA BIT DATA MUD TYPE DEPTH BIT NO. BIT NO, LSND WEIGHT ROT wr SIZE 10.2ppg VISCOSITY puwr MAKE 54sqc PVNP sowr TYPE 11 /18 GELS AVG DRAG SERIAL NO 6/11/16 APIWL MAX DRAG DEPTH OUT 2.8 HTHP WL TRQ BTM DEPTH IN 9.8ml/30 min SOLIDS TRQ OFF FOOTAGE 9.5% HOLE VOLUME PUMP PRES ADT/AST 466bbl III / MBT PUMP NO WOB2 17.5 11211 ph LINER SZ RPM 1 8.8 5.51611 LGS SPM 1 TFA 4.9% III PIT VOL GPM2 JETS 108 III IIIII DAILY MUD SPS 1 BIT COST $29901 30 140 I 30 I 40 TOTAL MUD SPP 1 DULL $567025 III III COMPANY MUD wr GRADE MI III III ,B~~:ØEeGRIPTION BHA NO OD BHA LENGTH 31/2" DATE LAST 31/2" INSPECTED: HOURS ON JARS: ': TIME I ËND HOURS I OP$CODE 12:00 AM 01 :30 AM 1.50 CLN_OUT 01 :30 AM 03:30 AM 2.00 CIRC 03:30 AM 04:00 AM 0.50 CIRC 04:00 AM 08:30 AM 4.50 TRIP _OUT ~- EVAL 08:30 AM 09:00 AM 0.50 09:00 AM 10:30 AM 1.50 EVAL 10:30 AM 05:00 PM 6.50 EVAL 05:00 PM 06:00 PM 06:30 PM 06:00 PM 06:30 PM 11:30 PM 1.00 ~ 5.00 EVAL PREP BOPE Jolly Drilling Report: CD 1-14 04/27/2001 SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/ AST / WOB2 RPM 1 TFA EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 0412412001 INJECTION INJECTION WELL CD1-19 SOURCE WELL CD1-14 RATE (bpm) PRESSURE (psi) INJECTION FLUIDS ( Daily Drilling Report Rig Relase - h~: Progress: 0 Est Cost To Date $ 3000000 Shoe Test: 16.1 ppg EMW DRILLS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 0411912001 0412712001 LAST H2S DRILL LAST CONFINED SPACE LAST FIRE DRILL 0412512001 LAST SPILL DRILL 0412712001 FUEL & WATER FUEL USED 1986 DRILL WATER USED - BBLS POTABLE WATER USED· BBLS o 90 WEATHER & PERSONNEL DATA TEMP of ·14 WIND SPEED 6 WIND DIRECTION 10° CHILL FACTOR of -23.97 0 JETS PHILLIPS IIIII 0 PERSONNEL 0 BIT COST CONTRACTOR 25 0 PERSONNEL 0 DULL TOTAL VOL (bbl) MISC PERSONNEL III 0 GRADE TOT FOR WELL (bbl) SERVICE 17 III PERSONNEL TOTAL 48 DRIL:LPIPE DAT'''' ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH 2.563 13.30 S-135 3-1/2 I.F. 2.750 15.50 G·105 3-1/2 I.F. HOLE SECT 51P1 51P1 51P1 51P1 51P1 51P1 51P1 I PHASE ope Making Hole Making Hole Making Hole Making Hole Evaluation Evaluation Evaluation 51P1 51P1 51P1 Evaluation Making Hole Making Hole OPERATIONS FROM 0000 - 0000 Clean out cmt f/ 13,875' to 13,936' Circ hole clean Flow ckeck - pump dry Job - blow down top drive Trip out wIG 1/8" bit & 7" csg scraper Rig up 5chlumberger sheaves PJ5M - P/U USIT/GR and Well Tractor RIH w/logglng tools to 13,833' tool stopped - ran first logging pass f/ 13,800' to 11,983' - RIH power up Well Tractor and run logging tools to 13,931'· ran USIT/GR f/ 13,931' to 11,983' - log showed good emt 1/13,931' to 13,370' Rig down 5chlumberger Pull wear bushing - set test plug - prep to test BOPE Test BOPE· pipe rams blind rams choke and kill line valves choke manifold valves floor valves Page 11 11:30 PM 12:00 AM 0.50 24.00 PREP Daily Drilling Report: CD 1-14 04/27/2001 (' S1P1 Making Hole manual and IBOP on top drlve( J psi low and 5000 psi high for 5 mlns. - Hydrll to 250 psi low and 3500 psi high for 5 mlns.- performed accumulator closure test· test witnessed and approved by John Crisp AOGCC Pull test plug and Install wear bushing Supervisor: DON MICKEY Page 12 Well Name: CD1-14 4/26/01 Date: Supervisor: D.Mickey Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/8" 40# L-80 BTMC X 7" 26# L-80 BTMe Casing Setting Depth: Toe Hole Depth: 12846 6,436' TVD 3,586' TMD 2,365' TVD Mud Weight 10.2 ppg Length of Open Hole Section: 9,260' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 601 psi + 10.2 ppg 0.052 x 2,365' EMW for open hole section = 15.1 ppg Used cement unit Rig pump used Pump output = bbls pumped Fluid Pumped = 19.0 bbls Fluid Bled Back = 0.0 bbls yes #2 800 psi 700 psi IIHIIIII IIIIIIII~IIIIIIII MME: Úr\JEc '.' I ONE~NúJËTIèJ<s - I 600 psi /.~ ~ £00", I ~ 400psi / ~ £00 "'; 2CO psi 100", ( ~ LEAK-OFF TEST ~CASING TEST -f,,"",' LOT SHUT IN TIME -k- CASING TEST SHUT IN TIME -+- TIME LINE o psi ~Å o 10 20 30 BARRELS 40 so NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE (;fJ [~~~~~~~~~~~~=~I~~~~~~~~~~~~~~I~=~~~p-~I~~~~I ! ! 1.0 ¡ 121 psi ¡ :----------------i----------+----------------t : I 2.0 : 162 psi I :---------------i------------i----------------f : I 3.0 : 177 psi I :---------------~-------------i-----------------. I : 4.0 : 192 psi I :----------------~----------.---------------. ¡ ! 5.0 ! 207 psi ¡ r--------------l------ã:õ-----¡---232-ps¡--1 r--------------T-m-j:õ-----r--2siïp-ši-1 ....--------------.,--------------1-------...--------.. L------------j----~:..~----l..:-~~~.P-~!---i ! ! 9.0 ! 308 psi ! E=::=::I=1fE:EJ;~;EJ L____m______L__~..2·<!____L__~~~J~_~!_j ! ! 13.0 ! 439 psi ¡ :---------------i--------- ----- -'1-----------------t : : 14.0 I 459 psi : :----------------i---------------"i-----------------f : : 15.0 : 495 psi : :--------------~--------------+---------------. : : 15.5 : 505 psi : :----------------~-------------+---------------~ ! ! 16.0 ! 515 psi ! ...---------------.,--------------~----------------T ! ! 16.5 ! 530 psi ¡ r---m-------l-----f7:õ----T--s4s-p-šr-1 r-------------¡-----17:Š----r--Š7Õ-p-š¡--1 F=::::::=:=j::~~f-~~-=::F~~~:*~~:! r-------------¡- - - -19:Õ- - - T - - 6õ-i pši - -! I; . : SHUT IN TIME : SHUT IN PRESSURE ..._-------..._-----~---------------------------------- ! 0.0 min ! ! 601 psi ! ¡-----------;----1---------------t------------:---t I 1.0 mln I I 560 pSI I :-----------------I---------------'1-----------------f : 2.0 min : : 555 psi : :---------------~--------------~----------------. : 3.0 min I : 545 psi : :----------------~---------------~-----------------. ! 4.0 min ! ,¡ 540 psi ! f ------ ----:---1----------- ----y------------:---: : 5.0 mln : : 540 pSI : r-----------;----1---------------y------------:---1 ~--~.:Q-~!~---~--------------~---~~~J~-~!---i I 70 . I I 530 . I ~----.:---~~~-~--------------+------.P~~---t ~---~.:Q-~~~---~----------m--+---~~~-t>-~~---i : 9.0 mln : : 530 pSI : [~~iQ~9~[6~~1~~~~~~~~~~~~~~~I~~~~~~j?~~~~~1 '__' Á Stbsidiary of PHILLIPS PI: I HULI:UM ~"'AN T CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE C~~~~~~~~~~~~~~¡~~~~~~!~~~~~¡~~~~~~j?~!~~~~~ I I I I ~--------------t---------------t----------------~ I I r I ~- -- --------- -- -+---------------+-- ------ -- - ------1 I I . . ~--- ------------+--------- - - ----+ -----------------i I I . I ~- -- ------ --- ---i--------- -- ----i----- -----------4 I . I I I . . I :---------------- ~ ---- ------- ----~---------------~ I I . I I I I I I I I I .---------------T-- -- - --..---- ---T-----------------y I I I I I I I I I I I I ....---------------1' ----- ----- --- --.,----------------~ I I I I I I I I I I I I ...____________ ---+---- -----------.- -----..- ----- ----t , I , I : : : :~ ...------------ _MM. - _______ ___ ____.________ - ____ ___... I I I , I , I , t.___________ __ __:_________ ______1_ _____ _ _________...: I I I I I I I I . I , I '---- -------- ----"'------------ ---.&.- ----------------' I I I I I : : : :----------- -----1--------------- t- ---------------1 ~-------- -------t-------- - ---- --+---------- ------~ I I I I !----------------+---- ---- ---- - --+----------------~ I I I I , I I I ~---------------t---------------t--- - ------ -------! ~------- --------i -- ---------- ---4---- ------------4 I I I , I I I I :------- - ---- - ---~ ---------.. ----- ~ ------------ ----..; I I I I I I . I :---------------4---------- ----- ~------------ - ---..: I I . r I I t I I , , , L~~~_I~!.!~~_L------------~~~~~!.~~!-'~,E ! 0.0 min ! ¡ 0 psi ¡ .....------ ---- ----..- --- ----- -- ----.- ---------------.... ! 1.0 min ¡ ¡ ! 1-______________... _ ______ ________4._ ----- ---- - -----..... ¡ 2.0min ¡ ! ¡ '-_______________ 4- __ _ __ ______ _ __.&__ __ __. _________-' ! 3.0min ¡ ¡ ¡ C=~~~~~[6~~:L~~~~~~~~~~~~~¡~~~~~~~~~~~~~~~~~ : 50min I I I~, ~----.:----------+---------------t-----------------' , : 6.0min : : I :- ----------- ---- 1- --- --- - - -- ----1--- -------- ------} ~--Z.:9--~~I]---¡---------------¡-----------------i ! 8.0min ¡ ! : ,.. ---------------,.-- -- --- - - -- ----T --- ------- ------, L-~:º--~~~---i---------------l---------------_Ì L--!Q:.º-!!!~f]--l---------------l----------------J I 15 0 . I I I ~-----:.--!!!~I]--f---------------t- --------- ------~ : 20.0 mrn : : : 1-------- --------4------ ---- - ----.- - ----------- ---... L_~~:.º_!!!~f]__l_______________l________________j ! 30.0 min ! ¡ ¡ '-____ _____ __ __ _ _... ____ ______ ___ __4._________ __ ___ __...I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Re: CD1-14 packer placement/logging requirements ~) Subject: Re: CD1..14 packer placement/logging requirements Date: Wed, 28 Mar 2001 08:27:27 ..0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <vjohnso1 @ppco.com>· ) JO\~o~'b Thanks Vern...this was an easy one. Tom Vernon T Johnson wrote: > Tom, > > That sounds like a good way to do it. We will plan on running the extra 7" > casing. > > Vern Johnson > > > > > > > > > > > > Varn, at ai, > With a minor change or addition, you plan will bEl acceptable. Is is > possible to > add maybe 2 joints of 7" casing thereby moving your float collar 80+ feet > down > hole? This should allow you to be able to see the top of the Alpine and do > it > before drillout (provided the plugs bump). > If you can accommodate this change, your proposal will be acceptable. > Thanks for > working with me on this one. > Tom Maunder, PIE > Petroleum Engineer > AOGCC > > Vernon T Johnson wrote: > > > Tom, » > > As discussed this morning, we plan on running an electric line "tractor" > > conveyed CBL on CD1-14 at Alpine. It is preferable to run the CBL logs > > prior to drilling out the float equipment. This means Jogging from +/- > > 14087' (17' MD above the top of the Alpine) to +/- 13100' MD (344' MD > above > > the packer top). Provided the plug bumps and the cement job goes as > > planned, we feel that this will provide adequate proof of isolation > above Tom Maunder <tom......maunder@admin.state.ak.us> 03/26/01 02:14 PM To: Vernon T Johnson/PPCO@Phillips cc: Chip AlvordlPPCO@Phillips, Scott D Reynolds/PPCO@Phillips Subject: Re: CD 1-14 packer placementllogging requirements 1of2 3/28101 12:27 PM .\ ,J ) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 28, 2001 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska, 99501 Re: Application for Sundry Approval - Temporary Shutdown of Drilling Operations CD1-14 Dear Sirs: Phillips Alaska, Inc. hereby applies for Sundry Approval to temporarily shutdown drilling operations on well CD1-14 with Doyon rig 19, at Alpine. It is intended to move the rig off CD1-14 in order to drill the Nigliq 1 well during the short exploration season. It is planned to return to CD1-14 and finish drilling the well after drilling the Nigliq well (approximately March 25). Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for securing the well. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~eIY,/ /?<¿,-, , Vern Johnson Drilling Engineer RECEIVED MAR 0 1 Z001 Attachments Alaska Oil & Gas Cons. Commission Anchorage cc: CD1-14 Well File / Sharon Allsup Drake Chip Alvord Mike Erwin Meg Kremer Gracie Stefanescu Lanston Chin ATO 1530 A TO 868 A TO 810 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @anadarko.com U' , I.) ; (.~ ; : ,¡ ¡ \ ; t\ ¡ lj ¡ ~ \~ /"..\ L · 1> ) ') h-<; ( \ JM rt ?JÞ1&~ cør STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ Operational shutdown _X Plugging _ Pull tubing _ 5. Type of Well: Development__X Exploratory _ Stratigraphic __ Service Re-enter suspended well_ Other Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) D F 56' feet 7. Unit or Property name 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3'15' FNL, 2"1.-82' FWI..., Sec. 05, T1 'I N, R.5E, UM At top of productive interval 1008' FNL, 1692' FEL, Sec. O:j T11 N, R5E, UM (planned) At effective depth 504' FNL, 524', Sec. 11, T11 N, R5E, UM (planned) At total depth 235' FNL, 688' FWL, Sec. 11, T11 N, R5E, UM (planned) 12, Present well condition summary Total depth: measured true vertical Colville River Unit 8. Well number CD1,·'!4 9. Permit number / approval number 201-038 10. API number 50-103-20371-00 11. Field / Pool Colville River Field, Alpine Oil Pool 3639 feet feet shoe depth Plugs (measured) 2400 Effective depth: measured :3Ei 5S} feet float collar depth Junk (measured) true vertical 2365 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 77' 16" Cemented to surface 114 114 Surface 3,602 9.625" 694 sx ASL+ 230 sx Class G 3,639 2,400 RECEIVED Perforation depth: measured None MAR 0 1 ?nOî true vertical None Tubing (size, grade, and measured depth 45" 12.6 ppf @ +/- 2"700' (planned) Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) no packer, no SSS\/ 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: March 25, 2001 16. If proposal was verbally approved Oil__X Gas Tom Maunder 27 -Feb-OØ Name of approver Date approved Service 17. I herebycertify that V1e foreç¡owg is true and correct to the best of my knowledge. Suspended __ Questions? Call Vern ,Johnson 265-6081 Signed "a~ ~~ Title: Drilling Engineering Supervisor Date 28~- ùml Conditions of approval: FOR COMMISSION USE ONLY Notify Commission so representative may witness I Approval no. '2 r. l- ~ Plug integrity _ BOP Test Location clearance __ --...Jl) V¡-, Mechanical Integrity Test __ Subsequent form required 1 O-__Ð~~Ç::,.. '~,\~ ':. ~\\~~~ c....\ ~ <.. ~\ \~ (t~~\ \ ~C~'\.~~<g..~'to" ~"((.." ~"~ ~~~""'~ ~ - Date á- Ý-OI Commissioner Approved by order of the Commission Form 10-403 Rev 06/15/88 . ORIGINAL SUBMIT IN TRIPLICATE O\ÞS '} \ Alpine: CD1-14 Temporarv Shutdown of DrillinÇl Operations -ProÇlram outline 1. Drill 12-1/4" hole to TO, as per drilling program. 2. Run and cement 9-5/8" casing as per drilling program. Note: displace the top plug with mud. 3. RIH with excess drillpipe and pull out laying down same. 4. Nipple down the diverter. 5. Install FMC unihead. 6. Pressure test casing to 2500 psi. (AOGCC requirement). 7. Pick up and RIH with +/-2700 ft of 4-1/2" tubing open ended (2000+ ft TVD). For 4-1/2" 1ST-Mod connections, make up the connections to the base of the triangle for the first 10 joints. Take the average torque and make up the remaining joints to that figure, verifying correctness every 10 joints. 9. Make up the tubing hanger to the last joint of tubing and roughly orient the completion so that the hanger matches up with the centering guide in the tubing bowl. 10. Sack out and recover landing joint. Install the 2-way check (in the lowermost 'Cameron' profile in the wellhead). P/U the landing joint and M/U to the tubing hanger. Then internally pressure test the hanger seals to 5000 psi. 11. Pressure test the casing to 2500 psi. 12. Remove the landing joint. 13. Conventionally circulate diesel to freeze protect through the tubing. 14. Shut in the well on both the tubing and annulus sides. R/U the FMC lubricator and install the SPV in the lower 'Cameron' profile. Ensure all surface valves are in the closed position. 15. RDMO Doyon 19. RECEIVED MAR 0 1 2001 Alaska Oil & Gas Cons. Commission Anchorage Re: CD1~14 Temporary Shutdown of DnDing Operations ) Subject: Re: CD1·14 Temporary Shutdown of Drilling Operations Date: Wed, 28 Feb 2001 09:37:01 ...0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Vernon T Johnson <vjohnso1@ppco.com> CC: Chip Alvord <calvord@ppco.com>, Sharon Allsup-Drake <sallsup@ppco.com> Vern, As discussed, this proposal is acceptable. Tom Maunder, PE Petroleum Engineer AOGCC Vernon T Johnson wrote: > Tom, > > As discussed yesterday, we intend to temporarily shutdown drilling > operations on CD1-14, at Alpine. The 12-1/4" hole will be drilled to +/- > 3639' MD (2400' TVD) and 9..518" casing set and cemented. We will test > casing, nipple down the diverter, install the wellhead and run a tubing > string to +/... 2700' so that diesel can be circulated to freeze protect. > The tubing string will be landed and a tree installed and tested prior to > moving off. We expect to be moving off the well March 2. > > The temporary shutdown is being done so that the rig can be used to drill > the Niglik 1 well during the short exploration season. It is planned to > return to CD1-14 and finish drilling the well after drilling the Niglik > well (approximately March 25). I will foreward an application for Sundry > Approvals Form 10-403 today. > > If you have any questions please contact me at 265-6081. > > Vern Johnson U'-_·_~-·-:-~-···------'--··---·-·-· I Tom Maunder <tom maunder@admin.state.ak.us> I Petroleum Engineer I Alaska Oil and Gas Consèrvation Commission I I 1 of 1 3/1/01 11 :08 AM ) ~~~~E : F !Æ~!Æ~~~~ / ALASKA OIL AND GAS / J T tlìCOlVSERVATIOlV COMMISSION . ames ran am Drilling Engineer Supervisor Phillips Alaska, Inc. POBox 100360 Anchorage, AK 99501-0360 Re: Colville River Unit CDl-14 Phillips Alaska, Inc. Permit No: 201-038 Sur Loc: 315'FNL, 2482'FWL, Sec. 05, TIIN,R5E, UM Btmhole Loc. 235'FNL, 688'FWL, Sec. 11, TIIN, R5E, UM Dear Mr. Trantham: I' ) TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. A decision regarding your request for relief of the requirement for packer placement of 20 AAC 25.412(b) will be made after review of the bond log. Please contact Tom Maunder at 793-1250 when the log is available. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COlVIMISSION DATED this / þ ¿ßf day of February, 2001 dlfJEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CD1-14 Permit application ) :) Subject: CD1..14 Permit application Date: rue, 13 Feb 200116:33:00 -1000 From: "Vernon T Johnson" <VJOHNS01 @ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Scott D Reynolds" <SREYNOL2@ppco.com> I ·'Chip Alvordu <CAl VORD@ppco.com> Tom, As discussed, recent rig schedule changes have placed CD1-14 as the next well to be drilled by Doyon 19 at Alpine. A permit application was submitted today, and the expected spud date is Monday, February 19; so a shorter than normal review period is requested. It was previously planned to drill Nanuq 3 next, however warm weather has caused problems building the ice roads and pads, so Doyon 19 cannot leave CD1 pad as early as expected. Thanks for looking at this on such short notice. If you have any questions please contact me at 265-6081. Regards, Yarn Johnson 1 of 1 2/13/01 4:50 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service 4t Development Gas ) 1a. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address Redrill Deepen Type of Work 2. 3. 4. P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 315' FNL, 2482' FWL, Sec. 05, T11 N, R5E, UM At target (=7" casing point) 1008' FNL, 1692' FEL, Sec. 03 T11 N, R5E, UM At total depth 235' FNL, 688' FWL, Sec. 11, T11 N, R5E, UM 12. Distance to nearest 13. Distance to nearest well Property line Alpine CD1-16 235' S. of Sec 2 feet 17.2' at 539' 16. To be completed for deviated wells Kickoff depth CD1-14PH:250' CD1-14: 13472' Maximum hole angle feet 18. Casing program size Hole 42" 12.25" ) bt 1,,\ jlV\ H/ t.-1 VtJ Stratigrap~iC Test Develo~ment Oil )l;1Þ Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool 5. Datum Elevation (OF or KB) DF 56' feet 6. Property Designation (). 2..«6(:) AD~~ ADL3155g~S- }6 7. Unit or property Name Colville River Unit 8. Well number CD1-14 9. Approximate spud date 11. Type Bond (see 20 AAC 25.025) Statewide Number #59-52-180 Amount 02/19/2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 19269' MD 2560 6876' TVD feet 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Feet 89.73 Maximum surface 2410 psig At total depth (TVD) 3086 at psig 6820' TVD.SS Casing 16" 9.625" Setting Depth Specifications Top Bottom Weight Grade Coupling Length MD TVD MD TVD 62.5# H-40 Weld 77' 37' 37' 114' 114' 36# J-55 BTC 3602' 37' 37' 3639' 2400' 8.5" 7" N/A 4.5" BTC-M IBT-M 26# 12.6# L-80 L-80 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured true vertical Casing Size Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot 14132' 37' 13468' 32' 14169' 1 3500' 6846' 6670' 37' 32' Plugs (measured) feet feet Junk (measured) Cemented RECEIVED FEB 13 2001 Alaska Oil & Gas Cons. Commission Anchorage BOP Sketch 21. I henby certify that the foregoing is true and correct to the best of my knowledge Refraction analysis Diverter Sketch Seabed report Signed ..,I ~ \ (I.Ac.n~,-,- Permit Numb~/_ 038 I ~6-' ~O~ - 2..D3'7l- ôO Conditions of approval Samples required Yes Hydrogen sulfide measures e!.) No Required working pressure for BOPE 2M 3M Other: '..)F<~<~::d¡\LL\l_ ~~i/.-";r'5f~ :_~.' _~., ,t 'C) T ay!or Sí::<::ìmount Approved by Form 10-401 Rev. 7-24-89 Quantity of cement (include stage data) Pre-installed 694 Sx Arcticset III L & 230 Sx Class G 180 Sx Class G Tubing Measured depth True Vertical depth ORIGINAL Drilling program X 20 AAC 25.050 requirements X ~ 1:) ,1.. ~.... t S ....(1",- Title D(illin~ Toam I Q..,.d~r Commission Use Only I Approval date "7 _I / _ /'"'1 I See cover letter for OC ft::P L/ Other requirements ~ Mud log required, Yes ~ Directional survey required ® No 10M 15M :::satS,,~\ ~\>\'(è~ 5M Commissioner by order of the commission Date , ~ kfø ""2..øÐ \ "J - / ~---O! Dat~ Submit in triplicate ) ') CD1-14 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole /9-5/8" CasinQ Interval Event Risk Level Conductor Broach Low Well Collision None Gas Hydrates Low Running Sands and Gravels Low Abnormal Pressure in Surface Formations >2000' TVO Lost Circulation Low Low .8-1/2" Hole /7" CasinQ Interval Event Risk Level Abnormal Pressure in Moderate Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M itiqation Strateqy Monitor cellar continuously during interval. N/A Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run gravel isolation string. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M itiqation Strateqy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. Alpine formation may be abnormally pressured due to gas injection from CD1-06. f' E H2S drills, d~tection systems, alarms, standard well 1\ eEl VED control practices, mud scavengers FEe 7" 2001 .. . I\/aska U"J & M Itlqatlon Strateqy I Gas Cons. Comm' Reduced pump rates, reduced trip speeds, real time Anchorage ISS equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Alpine formation may be abnormally pressured due to gas injection from C01-06. Horizontal section may be depleted causing lost circulation H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low ) Alpine: CD1-14PH (Pilot Hole) & CD1-14 ') Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. 2. Drill 12 114 inch hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8 surface casing. 4. Install and test BOPE to 3500 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 Y2" hole to a point +1- 1001 TVD below the base of the Alpine Sand. 8. Set 500 ft cement plug #1 from TD to +1- 13661'. 9. Set 350 ft cement plug #2 from +1- 13661 to +1- 13311'. 10. RIH with drilling assembly. Dress off plug #2. Kick off at +1- 134721 and drill sidetrack to intermediate casing point in the Alpine Reservoir. 11. Run and cement 7 inch casing as per program. Top of cement +1- 1000 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x T' casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 12. BOPE test to 3500 psi. 13. Rig up Schlumberger wireline and run cased hole logs to determine cement quality. 14. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 15. Drill 6 1/8" horizontal section to well TO. 16. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 16. Displace well to brine and pull out of hole. 17. Run 4 Y2, 12.6 #, L-80 tubing with SSSV nipple, production packer and XN nipple. Land hanger. 18. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20. Circulate tubing to diesel and install freeze protection in the annulus. 21. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi 130 mins. 22. Set BPV and secure well. Move rig off. ') ') Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-16 will be the closest well to CD1-14 (17.2' at 539' MD). Accounting for survey tool inaccuracy, the ellipse separation between these wells will be 12.6' at 565'. There is also a deep crossing with the open hole section of CD1-06. At 13,500' the separation between CD1-14 and CD1-06 is 649' but ~ the ellipses of uncertainty overlap until 13680'. The minimum separation through the interval is 649'. CD1- éo 'fi.j3 06 is a horizontal injector, currently on injection; therefore it will be shut in prior to drilling CD1-14. To l~u/é-3 mitigate the risk of collision, In-Field Referencing (IFR) will be applied to CD1-14 while drilling. IFR has S"lJDt1t(. already been applied to CD1-06. h:vt M';', c{'Sf¥4..A. F"'ht th<..J Drillina Area Risks: þ"t~ Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost .tI:> circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. The Alpine sand may be gas charged or abnormally pressured due to gas injection in CD1-06. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpinq Operations: Incidental fluids developed from drilling operations on well CD1-14 will be injected into the annulus of another permitted well on the CD1 pad. The CD1-14 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 20001 TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 1000' of cement fill above the top of the Alpine. Due to the geometry of the well a longer than normal cement column is planned above the Alpine. Also, it may be difficult to obtain a cement bond log after completing the well, so it is planned to perform electric line logging operations after cementing the 7" casing, prior to drilling the 6-1/8" hole section. We request that CD1-14 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW1s open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-5001 thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estima~ËYC E I V E D Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 PP9) * (0.052) * (2400') + 1,500 psi FCB 13 2001 = 2,998 pSI L Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. Alaska Oil & Gas Cons. Commission Anchorage The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi ') ') CD1-14 & CD1-14 PH DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1 18" point - 12 1,4" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 1 00 - 200 Initial Gels 4-8 10-15 10 minute gels <18 1 2 - 20 API Filtrate NC -10 cc I 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 -10.0 9.0 - 9.5 KCL 6% Surface Hole: A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel I polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ') ) Colville River Field CD1-14PH Pilot Hole - Prior to Sidetracking Updated 02/12/01 RKB - GL = 37' ~ Wellhead . . ~::-: :-:.~ 16" Conductor to 114' j . 9-5/8" 36 ppf J-55 BTC .. Surface Casing @ 3639 ' MD / 2400' TVD cemented to surface 9.8 ppg drilling mud in hole > Pluq #2 : 350', 17 Ppq (top at +/-13311') Cement Plug Top Alpine Reservoir at 13888' MD / 68381 TVD j ~ j ~ j ~j ;¡~¡ ~ ¡: ¡ ~;f ~ ¡ ~; ¡ ¡ ~ ¡ ~; ~ ¡!!i·~!~~i!~~!.·i; 1!¡!:~¡~~'I~·~··i¡li ~ ~ ¡ ¡ ¡ ~ ~; ~ ~ ~ ¡ ¡~ ~ ~ ~ ¡ ~ ~ ~; ~ ~ ¡ ~ ~ ¡ ~ ~ ~ ~ :: ::~~~~::::~:~:~:~:::~:.:.~;::~ Top of cement plug dressed off to 134721 MD / 66581 TVD (+/- 64º inc.) Top of Cement Plug #1 at +/- 13661 -IJ 500 ft ft Pilot Hole TD at 14161' MD /6956' TVD (+/- 64º inc.) r"'- ~i'i'il I ) ) Colville River Field CD1-14 Injection Well Completion Plan mmi.':.:,·."'::::.:':.'.'.··.'.¡".'.:. ïIm 'l'I'l4_1I:~'~::::::~:: 1~:~V Nipple (3.812" 10) at 1700' TVO mm Isolation Sleeve with OB-6 No-Go Lock (3.812" 00) run in profile 1,I,Ii 9::/:" 1::"p~:J:::" B:~ control lines at 1820' T;';;;~;:;~3:8;22~ ~6)0! t~1 b~B-6 Iii. Surface Casing installed later @ 3639' MO 1 2400' TVO cemented to surface Updated 02/12/01 Packer Fluid mix: 9.6 ppg KCI Brine with 20001 TVD diesel cap 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet lube pipe dope Tubing Supended with diesel Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco DB Nipple 2300' 1820' 4-1/2", 12.6#/ft, IBT-Mod Tubing S3 Packer (c/w handling pups) 13444' 6646' 4-1/2" tubing joint (1) R2 HES "XN" (3.725" ID) - 65 deg 13490' 6665' 4-1/2" 10' pup joint WEG - 65 deg 1 3500' 6670' Top Alpine at 14,104' MO 1 68411 TVO :ff>~ Baker 53 Packer at +/- 13444' «660' MD above to top Alpine) ":::: ~ ¡ [¡¡Ht¡n>:',,_____ ____ ___ ":: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~:: ~! ~:: ¡: Ja____ _____ _____ _____ ____n___n____ ___n_______________ n___ _____, Well TD at l 19,269' MD I i ";'::::::" 6876' TVD i ···:.<¡g'ttlULEmdEmUUUd'------------------------------------------------------_: TOC @ +/- 13104' MD 6388' TVD (+/-1000' MD above top Alpine) 7" 26 ppf L-80 BTC Mod Production Casing @ 14,1691 MD 1 68461 TVO @ 87º - j""'- ......., ¡,II,I: mm: lilt - .........! ) ) Colville River Field CD1-14 I njection Well Completion Plan Formation Isolation Contingency Options -"""l Ili,l: Updated 02/12/01 16" Conductor to 114' 4-1/2" Camco BAL-Q SSSV Nipple (3.812" ID) at 1700' TVD Isolation Sleeve with OB-6 No-Go Lock (3.812" OD) run in profile Dual 1/4" x 0.049" sls control lines at 1820' TVD=2300' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 3639' MO I 2400' TVD cemented to surface WROP-2 SSSV (2.125"10) wi OB-6 No-Go Lock (3.812" OD) - to be installed later 4-1/2" 12.6 ppf L-80 IBT Mod. tubing run with Jet Lube Run'n'Seal pipe dope (A) Banzai ECP Assemblv - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBO) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe I Entry Guide (C) Open Hole Bridqe Pluq Assemblv - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Baker 83 Packer set at +/- 13444' (-660' above top Alpine) Well TD at 19,269' MD I 6876' TVD Toe @ +/- 13104' MD (+/- 1000' MD above top Alpine) 7" 26 ppf L-80 BTC Mod Production Casing @ 14,169' MO I 6846' TVD @ 87° ) ') CD1~14 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MDrrVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 3640 I 2400 14.2 1086 1532 7" 141 69 I 6846 16.0 3095 2410 N/A 19269 I 6876 16.0 3111 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib./gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2401') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3095 - (0.1 x 6846') = 2410 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3095 - (0.1 x 6846') = 2410 psi ) ) Alpine. CD1-14PH CementinQ ReQuirements CD1-14PH Cement Plug #1 : 14161' MD to 13661' MD = 5001. Slurry: Cement with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. 500' X 0.3941 fe/ft X 1.15 (15% excess) = 226.6 fe => 196 Sx @ 1.16 fe/sk CD1-14PH Cement Plug #2: 13661' MD to 13311' MD = 3501. Slurry: Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. 350' X 0.3941 fe/ft X 1.15 (15% excess) = 158.6 fe => 159 sx @ 1.00 fe/sk Alpine. CD1-14 Well Cementing Requirements 9 5/8" Surface Casing run to 3640' MD /2400' TVD. Cement from 3640' MD to 3140' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 3140' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: System: Tail slurry: System: (36401-1747') X 0.3132 fe/ft X 1.5 (50% excess) = 889.3 ft3 below permafrost 1747' X 0.3132 ft3/ft X 4 (300% excess) = 2188.6 fe above permafrost Total volume = 889.3 + 2188.6 = 3078.0 fe => 694 Sx @ 4.44 fe/sk 694 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 fe/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 14,169' MD /6846' TVD Cement from 14,169' MO to +/- 13104' MO (1000' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (14169' - 13104') X 0.1268 fe/ft X 1.4 (40% excess) = 189.0 ft3 annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume = 189.0 + 17.2 = 206.2 ft3 => 180 Sx @ 1.15 ft3/sk 180 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement : Cre~t-e~ b;n;:;;i;~~~-;-_n~F-;;~~uVuJ~hnson : Date platted: 12-Feb-2001 Plot Reference is CD1 -14 PB t Version#2. : Coordinates are in feet reference slot #14. : ¡True Vertical Depths are reference RKB (Doyon 19).j - BAK~=;æ HUG!!!:! r:',"TEQ Phillips Alaska, Inc.! Structure: CD#1 Well: 14PH Field : Alpine Field Location: North Slope, Alaska i _________________._____m__________n..____-' ==== PROFILE COMMENT DATA ----- Point KOP 4Deg Bid F niT rn EOC C40 9 5/8 Casing pt C30 C20 K-3 K-2 Albian -97 Albian-96 HRZ K-l LCU Miluveach A Alpine D Pilot Hole Tgt Base Alpine TD -------- -- ----- MD 250.00 583.33 708.78 1075,58 1747.43 2038.18 3132.95 3638.74 3652.60 4484.03 6816.67 7394,05 11712.87 12313.34 1 2844.53 13331 .84 13551.25 1 3791 .44 13846.87 1 3888.44 1 3934.63 14160.96 Inc 0.00 10,00 15.00 27.35 52.99 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64,34 64.34 64,34 64.34 64.34 64.34 64.34 64.34 64.34 128.00 128.00 130.00 106.96 93.88 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 90.93 Dir TVD 250.00 581 .64 704.08 1046.00 1556.00 1706.98 2181.00 2400.00 2406.00 2766.00 3776.00 4026.00 5896.00 6156.00 6386.00 6597.00 6692.00 6796.00 6820.00 6838.00 6858.00 6956.00 No rt h 0.00 -17.86 -35.02 -90.41 -154.76 -164.77 -180.78 -188.18 -188.38 -200.54 -234.65 -243.09 -306.23 -315.00 -322.77 -329.89 -333.10 -336.61 -337.42 -338.03 -338.70 -342.01 East 0.00 22.86 43.90 1 6 1 .48 584.49 832.18 1818.88 2274.74 2287.23 3036.59 5138.95 5659.34 9551 .80 10092.99 10571.74 11010.94 11208.69 11425.16 11475.12 11512.59 11554.22 11758.21 ....:0... ----.. ....,;;;¡;.,. ~ ---- ~ - - -- - - - - ~ ---I- _1--"'" - ---- -. .-.-- --- - - --- - - - -- - -- -- .. --- - - - - - - - --- ':!!ii! !iii! iiiI ~~ !ii! ~ = - - - . - - - - - - - - - - - - ___ ..._nm..........._u.....mmmm _ - ~- --- --- -- --~ ~- ==== V. Sect 0.00 23.15 44.46 1 62.93 586.92 834.74 1821 .58 2277.49 2289.98 3039.45 5142.08 5662.54 9555.51 10096.77 10575.58 11014.84 11212.61 11429.12 11479.08 1 1516.56 1 1558. 19 11762.21 Deg/100 0.00 3.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~ '~ ___________mm___________m___________ _____________mmm_____~__ ~ ~ ~ - - - - - - --- ---- -~ -- -- ~ ~- - - - - {PHILLIPS} - - - - - - - - ----- - - - - - Date plaUed : 12-Feb-2D01 Phillips Alaska, Ine.1 _ _ _ 00 _ uumuuun mm_mmuuu_m.u__..._uu_, : Created by michael For: V Johnson: , ' , , ¡ Plot Reference is CD1-14 Version#2. ¡ ¡ Coordinates are in feet reference slot # 14. j !True Vertical Depths are reference RKB (Dayan 19),: Structure: CD#1 Field : Alpine Field Well: 14 Location : North Slope, Alaska! ~1!2 ~ INTI::{..l On _ __ _______ __________u_____________~ ~~~= PROFILE COMMENT DATA ===== ----- Point ----- MO Inc Oir TVO No rt h East V. Sect Oeg/100 ~ KOP 250,00 0.00 128.00 250.00 0.00 0.00 0.00 0.00 Begin 40eg Bid 583.33 10.00 128.00 581.64 -17.86 22.86 26.51 3.00 Begin Fnl Trn 708.78 15.00 130.00 704.08 -35.02 43.90 51.53 4.00 West Sak 1075.57 27.35 106.96 1046.00 -90.41 1 6 1 .48 155.65 4.00 Permafrost 1747.43 52.99 93.88 1556.00 -154.76 584.49 411.12 4.001 I EOC 2038.18 64.34 90.93 1 706.98 -164.77 832.18 536.28 4.001 C40 3132.94 64.34 90.93 2181.00 -180.77 1818.87 1013.79 O.OO! 9 5/8 Casing pt 3638.73 64.34 90.93 2400.00 -188.17 2274.72 1234.40 O.OO! ! C30 3652.59 64.34 90.93 2406.00 -188.37 2287.21 1240.44 0.001 I C20 4484.02 64.34 90.93 2766.00 -200.53 3036.57 1603.09 0.00 K-3 6816.65 64.34 90.93 3776.00 -234.63 5138.92 2620.52 0.00 K-2 7394.03 64.34 90.93 4026.00 -243.08 5659.31 2872.36 0.00 Albian-97 11712.86 64.34 90.93 5896.00 -306.22 9551.78 4756.11 0.00 Albian -96 12313.34 64.34 90.93 6156.00 -315.00 10092.98 5018.03 0.00 ¡HRZ 12844.53 64.34 90.93 6386.00 -322.77 10571.73 5249.72 O.OO! -. !K 1 13334.15 64.34 90.93 6598.00 -329.93 11013.02 5463.28 0.00 IBegin Fnl Bld/Trn 13472.01 64.34 90.93 6657.69 -331.94 11137.27 5523.41 0.00 ¡LCU 13555.89 65.94 99.06 6693.00 -338.60 11213.00 5564.85 9.001 iMiluveach A 1 3869.1 5 75.20 127.37 6799.00 -455.42 11479.99 5793.37 9.001 I ¡Alpine 0 13977.57 79.27 136.47 ,6823.00 -526.02 11558.51 5892.58 9.00 iT gt/7 Csg pt 14168.91 87.00 151 ,98 6846.00 -679.68 11668.96 6080.10 9.00 IFni EOB 14449.43 89.81 151.99 6853.82 -927.21 11800.65 6360.48 1.00 I ¡Base Alpine 1 5091 .55 89.81 151.99 6856.00 -1494.08 12102.24 7002.60 0,00 iTgt/lntrmdPt 18069.28 89.81 151 .98 6866.00 -4122.89 13500.87 9980.32 0.00 'End Angle Drop 18098.34 89.52 151 .99 6866.17 -4148.55 13514.52 10009.38 1.00 IQ______ 19269.36 89.52 151.99 6876.00 -5182.35 14064.46 11180.35 0.00 700 - 1400 - ".-..... +- Q) Q) 2100 - '+- '--./ s:. +- 2800 - 0... Q) 0 0 3500 - U +- L Q) 4200 - > Q) :J 4900 - L f- I V 5600 - 6300 - 7000 - 7700 o - Created by michael V Johnson Dote plotted; 12-Feb-2DOl Plot Reference is CDI-14 PSI Version#2. Coordinates ore in feet reference slot #14. Vertical Depths ore reference RKB (Doyon Fi!~;;¡ BA.."OR Ii'~ niTH¡ I RKB Elevotion: 56' ~C(fo 9.00 Begin 4Deg Bid 14.65 Begin Fnl Trn 21.08 28.24 West Sok 35.74 DLS: 4.00 deg per 100 ft 43.40 55.03 Permofrost EOC ..... , --. C40 .'-<7 9 5/8 Cosing Pt ~.- é30 . .. C20 TANGENT ANGLE 64.34 DEG o 1400 3500 2100 2800 700 Phillips Structure : CD# 1 Field : Alpine Field Alaska, Inc. Well: 14 Location : North Slope, Alaska 90.93 AZIMUTH 11517' (TO PH TARGET) ***Plone of Proposol**" ~~............ " -__ Albian-97 .-..... Albian-96 ". HRZ AIPi~;-ò"'\~t~iluveOCh A Pilot Hole Tgt _.nnn< Bose Alpine TD 14 7000 7700 8400 9100 9800 10500 11200 11900 12600 13300 4200 6300 Vert i c a I Sect ion (f e e t) - > Azimuth 90.93 with reference 0.00 S, 0.00 E from slot #14 '.. K-3 K-2 4900 5600 ~~ -~- ~'- ).P!!~l~l~~ ? - .- - - ~~~ ~ .-, -'- r--.. Q; Q) '+- '-" s: õ.. Q) o o o L Q) > Q) :J L l- I V 6000 - 6300 - 6600 - 6900 - 7200 - 7500 Created by m¡chael For: V Johnson Date platted: 12-Feb-2001 Plol Reference is CD! -14 Version#2. Coordinates ore in feet reference slot # 14. Vertical Depths are reference RKB (Doyon 19). ulf!e ~ JNTF.} -~ ,"- 00 '\ 0( « ò0o, 00 <1- S· 'V'" ",(0 ~ò\ <0 ~~ ~0 " '\ '00 c,\) " +-" <ö"J" X' \>- ~"- ',- 'Öto.. 'Öto. ....00~ 'V c,,,,0) LCU,"- 'Ö<1' ~~~Ç6'to. :--.\'Î <y.O'0 Miluveoch ~'~~ ",0) ~~ Alpine D'·. . . Pilot Hole Tgt ", -,;¡ Bose Alpine TDt:ITJ s:-1., -<' 5100 5400 6000 6300 5700 Phillips Structure: CD#1 Field : Alpine Field Alaska, Inc. Well: 14 m_~________.____.____ ....___.._____________..____________________n Location : North Slope, Alaska i 151.99 AZIMUTH 11180' (TO TD) ***Plane of Proposal*** TARGET ANGLE TANGENT ANGLE 87 DEG 89.81 DEG \.00 -?> « ",0 '00 6600 6900 7800 Vertical Section (feet) -> 8100 8400 9300 7200 7500 8700 9000 Azimuth 151.99 with reference 0.00 S, 0.00 E from slot #14 FINAL ANGLE 89.52 DEG §"- '0,0« ~<!' Òj0 \"" \>-0 '" Ò) <y.<:'Ò 9600 ~ ~ ~ ~ - ~ --- ------- -- -- ----- - - ,PHllUpsì - - _ .m........ _ - --~-- - - - - - = ~ - - = :. - - - - - - - - - - '- = - - - - __ m.... n. ........__...__n..... ~ -- -..--- -- -----:--- - ~ .~ ",'V t!iJ 9900 10200 10500 10800 11100 11400 ,---------------------- . Crealed by m;chael For: V Johnson Dote plotted: 12-Feb-2DDl Plot Reference is C01-14 Version#2. Coordinates ore in feet reference slot #14. ¡True Vertical Depths are reference RKB (Doyon 700 o 700 0'Ò f>.\)~0 <0 i~<::p «~o'f. \<oc,"- <?J<¢e0; c,"- «,-0 o ~e «e\..oC .-- If- SURFACE LOCATION: 31S' FNL, 2482'FWL SEC. S, T11 N, RSE ~iii.!ii ~ HUGH6 INTEQ 1400 2100 «"- ,;po, CO f>.0 0\'O"J0 ,,0 ..C ---;'?> C C" ~ 2800 3500 Phillips Alaska, Structure: CO#1 Field : Alpine Field Ince Location North Slope, Alaska Well: 14 East (feet) -> 4200 4900 5600 6300 7000 7700 90.93 AZ +,,"J +" r¡.. n j;_______ 90.93 AZIMUTH 11762'(TO PH TD) ***Plane of Proposal*** 8400 9100 - - - - - - - -- -- -- -- - ~ ~-- - - - - ,PHilLIPS} - - ::::; -------- ¡¡: - ----------.-- - - - - - - ~ -- -- 9800 10500 11200 11900 12600 13300 14000 14700 PILOT HOLE TARGET LOCATION: 666' FNL, 1847' FEL SEC. 3, T11 N, R5E PILOT HOLE TO LOCATION: 670' FNL, 1601' FEL SEe. 3, T11 N, RSE ~ ,,0,"- /,?>1 /,?>'ô 00'0\) o,e \0e . 00 . 00 ",r&~0e :-.. yo: ~« ~'O' ~'O' 0«'-1... +- ::s,~:::"~V:R<?"'O oC,e \) .>....m.._.. . ~mm.... ..n..... .... .~. L'\ . <?J-<: . m m r ". ..~t::ITJ \,\<0 ~. \ 0'Ò "CO\) ~ b \> Tgtj7 Csgpt <:~ 00'0 \) Fnl EOS ~ ..¡e'0e <¢i>t >i:::,0~«' TARGET LOCATION: 1 008' FNL, 1692' FEL SEC. 3, T11 N, RSE INTERMEDIATE POINT LOCATION: 826' FSL, 128' FWL SEC. 2, T11 N, RSE TO LOCATION: 23S' FNL, 688' FWL SEC. 11, T11 N, RSE 1400 - 700 '-' o - 700 - 1400 m 2100 (J) 0 - 2800 C -+- :J ,..-..... - 3500 -+. CD CD -+- '-../ - 4200 I V - 4900 .~ - 5600 - 6300 - 7000 - 7700 ... 8400 ) ') Structure: CD#1 Field: Alpine Field Well: 14 .."............................. Creatod by michaol For: V Johnson Date platted: 12-Feb-2001 Plat Ralaranca is CDt-14 pst Varsian#2. Coordinates ore in feet rcference :slot 1114. True Vertical Depths orc referonce RKB (Doyon 1 g). Phillips Alaska, Inc. Location : North Slope, Alaska ...".............................. Rill. DAKDI HUGHEG .....~.~E~:!.?........... Q> QJ... 3~0 1 0 ~~~" 20 \, \ 30 \ \ \ 320 \ 40 \ 50 60 70 280 80 270 0 90 260 100 1 1 0 120 R£CE\VEÐ 140 FEB 13 2001 210 150 , "G \~ uU01missi~ 200 160 Alaska 0\\ Ò. \~'1::- I 190 180 @70 Anchorage Normal Plane Travelling Cylinder Feet All depths shown are Measured depths on Reference Well I I I I I I 300 & <à 400 @ 700~~ -., / 900 .:/'/ 1 500 ''', / / f7 \/500 / , / , / , / , / '. / / ~ )'/3600 ". 500 / \. 600 / '400 \. 800 / .... '" // , ·······....1190 '''',500 ".,../ 8__ ", // ···~200 ----,,_~OO 3500 ~< '- 500 / '", 600 e-..~9° 500 --..---...._~ / ' ",1300 ~. 600 ~"'---_____60(} .... " ". \ -~:I-................. 7 .... .. ................. '. 700 / / ~......--_?-? ' , """,,-1 400 \~ 800 // '------...-.......êOO '"....700 -'-~-.........~ "", ~. 3400 ~.... -~--......... 1500 X909 90Ò---'~-~ .... .--.........-- --...~ -------~-_ 1 600 / . 1 000 ~_OOO *-'-=. / , , ~ , ....~ / ."" ' ~~-~ 1 00 "...;J300 " 800 -., ---...._____ / \~ 1100 ------..........1200 2300 28?_Q_ ". ~---------~ 60 - ID·----~·-', -------__. 1300 \ ~--~ \.. -""'""--..._-- , 1 200 900· ~ -_________. " -----..-1..400 ,.,\ ~----............_------------ fJ])', --------....J. 500 80 ~ ŒD-::~~rl::?:;:o." ~ - ... 2000 --------_ ----::.:.:::::::.::.:::.:::.::~~?__-___ '\ 1300 ~ - 1 OOÕ----- -----___2~0 \ - 90 I I --~~~~~---~-~ I I I I I I I I I I - - ~ - 100 o 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 1 70 180 Created by finch V Johnson Date plotted: 12-Feb-2001 Plot Reference is CQ1-14 Versron#2. Coordinates are in feel reference sial /14. Vertical Depths ore reference RKB (Doyon --~- ~.i_iR- H'JC-HES Ti''<ÏF.Q 30 10 10 40 20 30 20 30 - <0 20 . 1100 f7 10 . 1000 o - 8, .900 f7 10 - ",----.... +- Q) Q) '+- '--'" 20 - ..r. +- ::J o (f) I V 30 - 8 B 40 - 50 - 70 - 90 - 100 I 30 20 I 10 Phillips Alaska, Inc. ......... ....-.... ---- -- ~ - ~.-. - - " PHILllPSl · . · . · . · . · . - - - . · . · . · . · . · . - - _. . .....-~~ ~~- --- Structure; CD#l Well; 14 Field : Alpine Field Location : North Slope. Alaska 50 East (feet) -> 60 70 80 180 110 120 I 130 I 90 100 I 140 I 150 I 160 I 170 \\ 600 , " .\ " " '", 700 " '"... ~ -......." " -............_2;00 ''-'---..,'-- '-~ 1300 '------- - 10 - 30 ~ - 20 ----------..~~- ---------[Ð - 0 - 10 ,,800 ." '". ".......... '·"'-....900 ~ ................ ----~.........---........ 1 000 --------__.......... 1 ~9.--/- 1700 __-.::~_=:.iioo .- ------____ 1200 ------------w- 50 - 20 If) o C -+- :::::J .....---@- 30 ___---~-49ô0 ------------- ",----.... -+. CD CD -+- '--'" - 40 I V ~' - 60 - 70 - 80 East (feet) -> Phillips Alaska, Inc. j Created by finch For: V Johnson! Structure: CD#1 Well: 14 ........ ............. .......... ~ .- - ~.-. {PHilLIPS} - - · -..-............-.........-....... . · . · . "----- --- ~ ---- ---_.__._...._._--~-~~--_.._-_._------- Dote plotted: 12-Feb-2001 Plot Reference is C01-14 Version#2. : Coordinates ore in feet reference slot 114. j ~True Vertical Depths ore re;;;~c~ RKB (Doyon 19)-1 1b&_I(fR-- WY.rlæS TNTF.Q Field : Alpine Field Locotion : North Slope. Alaska ~_._--- 120 140 160 180 200 I 220 240 260 280 East (feet) -> 300 320 340 360 380 I I 400 I 420 I 440 I 460 480 I 500 520 540 560 20 - /'¡;--- 'Z)~_,_¿ 300 ,,·------~-L~_~?_ 1500 ø 2200_............--- ----------- 1600 ...........-------- 1900 2000 --- ----~____~~;~2-;;_~-------:1.80~---.--------- 2000 ~ --~------ 2200..__----Cf) ..------- _3~-~---..--..--- - 20 o - --. --- - 0 ----. <0 ~~;:o::~~-~~;; __;:'00 1 60º--___ 1500 __----------- 1 ~-.-------.-.- 190~-----CÐ- ~--~----~------+-.- - 20 -------:?~~--- 20 - 1900 .----- - 40 60 - - 60 ~ +- Q) Q) - '---/ -L2Ð--...¿_~00 80!Jb ---.--------- 1500 - - - .. ~ 000 ..-----._____ - 80 UJ o C -+- ::::J 140 - "--.--__ 1 600 - - - -..J ~ ~~"----·~-------~_1700 1 30 Õ - - - _ -------___...... --....-------_____ ..l2~~-----___. 1800 1 400 -....- __-=-~ - :_-:~::-.:.-::.-~_ 1300 1 700 1500 ---~_=__:::::::'-",,_-. 1500 1400 1600 -~~~_ 1800 1 ;;~<=~~~::~~=_~cr';-~~. .--:- ~""-C. -'.=~~ .25~0 . . . _.:: 1" 2000 ------ --.----___ -----____________ 1700 -®- 160 ---------- -----~?~O ----...... ------.. ---......------ -------~ ~ - 200 - 100 100 - ®__..1200 -B--._-~= 120 - - 120 ~ -+, CD CD -+- '---/ ...c +- ::J o Ul I V I V 160 - ~' 180~ -"-..._~~_OO - 180 200 - --~.~..--1J3_~~__.__ --------. 2000 -~-------~~ --------~-229° ------ --------_ 2200 -----{]i) - 220 220 - ~ 240 -~Qò -240 120 I 140 I 160 I 180 I 200 I 220 I 240 I 260 I 280 I 300 I 320 I 340 I 360 I 380 I 400 I 420 I 440 I 460 I 480 I 500 I 520 I 540 560 East (feet) -> 1280 160 <6\ @- -\.'\ ---.../..../'.... '\.'\. ...-_..../'- "" ----- " ~ _~--~ðo \ " \ , , , \ \ 120 - _ID~_-_---190~_ 1m- ~.~~~__~=:~=~~_=________ 19~ -1m ___ _ ~_ _ _ _ __ 1900 ------_~~~_~~O-O - - - - - - - - - - - - - - - - - - - - - - - - - -4- - ~ - -------------. ------- -____ -----____ - 200 ----------- --- ----------------- ---~ -------------------~300 ------___ ~;;-------E.~O~- --------.-----______ 2900 ____--=====--=--=--=:::=-=-=.=-===~ - 240 --l~~______ _u___.___ -:-------..._____ __------- ~ 2700 Phillips Alaska, Inc. -..--------------------- ¡ Created by finch For: V Johnson: Structure: CD#1 Well: 14 Date platted: 12-Feb-2D01 Plot Reference is CD1-14 Version/J2. Coordinates ore in feet reference slot H 1 4.. Field : Alpine Field Location : North Slope. Alaska . . ¡True Vertical Depths ore reference RKB (Doyon 19).¡ . ~ÍÎlIi' BAKLit-- HUGHU TNTF;Q East (feet) -> 400 160 440 520 640 880 1200 920 960 1000 1040 1080 1120 1160 680 720 760 800 840 560 600 480 120 /& ////// //~2;;0 ....../...,....-- _.....-/-......- -_/- ~--~_/--_/ 2300 _-~--- --------- ---_._-~~~---------------- 80 ------/// 2500 //-// .--.--- __\9 ---------------- 2700..../-------- ----------.---- -(;5)- - ------- 40 _---~2~~./----//-- -- o ~. 1900 §------- 40 - ,--... +- Q) Q) '+- '---'" 80 - ....c +- ::J o (j) I V 200 - 240 -']I)-- __ ___ 280 - ---------- . ---------*__2500 ------------ -------------- -------------- ------. ~---_______ 2700 ~-*~ 320 - 360 - 400 440 480 640 750 1200 800 840 880 920 960 1000 1040 1080 1120 1160 680 720 520 560 600 East (feet) -> ~ - -- ---- ---- - - '{ PHIUJPS"£ - - . -n .. 1240 120 ~ 80 40 - 0 - 40 - 80 UJ o C -+- :J 120 ,--... ....... (1) (1) -+- '---'" I V .~ - 280 - 320 - 360 1240 1280 Phillips Alaska, Inc. Crealed by finch V Johnson Date plotted: 12-Feb-2001 Plot Reference is CD1-14 Version#2. Coordinates ore in feel reference slot 614_ Vertical Depths ore reference RKB (Doyon ~SE BAKER HUGHU Tl'<lF.Q Structure: CO#1 Well: 14 - - (PHIUJPS) - - . :..-_----------------- - - - Field : Alpine Field Location : North Slope, Alaska East (feet) -> 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 500 - 500 - X!'i9 /# fi&¿ 8300 ~ \ " /3_;:;:::/ // __-------~ ·---------~--!'-''"'--__._!'wo \ 400 - ;;¿?:;!''''2700 ,//29~0 /_____-- -..~/ ------...........~OO\ 9900 ::: ~:/ /~-~~:~:~::/------- --\\\ ':0 ~\~,5,,',0,~,\~"'" //370()_-- __ /---\\/- 3500 _----~----------------~ \\ _-~---------------'r-- \\ 100 - \ 3300 ~----------- \ - },g00 --~""--2iO-;---- 2300 \ ::~,~"~~~~~~~:~~--~~---------~"-----~~:: 400 -·---···----..-___.?~?O ---______ 3700 - 400 --.-:~\- ---------___ _ ~OO _ \ ----~_1 00 ---'\--___® \\\~----~;>200--------·~~-------·~-'~-~-3900 \\\ : ::: ~ -------~ % - I I 800 - 500 - 400 '~ - 300 - 200 -@ ---~~?-~--/~- - 100 ,---.. +- Q) Q) '+- ............ - 0 UJ o C -+- ::J ...c +- ::J o U1 I V 100 ,---.. - ([) ([) -+- '---'" I V --- 600 - 700 800 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 East (feet) -> \~<'\\ \5300 __ 49~___---~-~º----~------\- 4700 __--~-~- \ ____--/>43()'L---/--!50Ò\---/>-- \\ 41_00-/ \ \\ \ \ 6300 \ '\5 700 5900 61 O~_..--ŒD- 200 -JD- _ _ _ _ _ _29~~ _ _ _ _ _ _ ;~O? _ _ _ _ _ _ }~~O.., _ _ \4500 4700 4900 5100 5300 ~~---~;--------- 400 - ~--- 3500--- ---'3700~3900-- ---41 00 4300 "3\?Z\ - .~ . "3700' ~ - . . _. ~;o~ . . -c-: . -:. ~ ~o - . . - n -"~\,' - - . >4500- . . - . . -:'700 -!E)- - ~"'f~ºº-h-_;~~~_ 4300 4500 . - \-·----__~_______.~~O 4900 5100 \\ '''cD ~--________:3~ 5500 --\---- 5700 5900 ,---------___. 6100 \... ..-------.-- ~- \ \ ~-.--.~_ 4 700 \ 1000 - .-~------~.. '4900 ~-.-.......5100 \ '\ ---··------.._.?300 \ -------·---~?OO ' \ .----------2700 [TI] ~ --£® Phillips Alaska, Inc. V Johnson Structure: CO#l Well: 14 Created by finch Date platted: 12 -Feb-2001 Plot Reference is C01-14 Version#2. Coordinates are in feet reference slot # 14_ Vertical Depths ore reference RKB (Doyon I'lIfli! BAKER HUC_S TJ'I.'TF.Q Field : Alpine Field Location : North Slope, Alaska East (teet) -> .3000 .3200 .3400 .3600 .3800 4000 4200 4400 4600 4800 5000 5200 5400 5800 5600 6000 6200 6400 1200 - 0' "V ----sØ "\ --------- 4300 1000 - ... .3 900 ..______/ 800 -'ê§Y- ------ 5500 600 - 400 - ,---... -+- Q) Q) '+- '---'" 200 - ;sD-/- ....c -+- :J o U1 I V 600 1200 - 1400 .3000 .3200 .3400 .3600 .3800 4000 4200 4400 4800 4600 5000 5200 5400 5600 5800 6000 6200 6400 East (feet) -> ...... ........... ..... <~l - - . ..__ mnnn on ...n_m . - - . - " - " ~ \...~ -:;: -- 6600 6800 7000 7200 - 1200 - 1000 800 5700 ----*------------ ------fJD- 600 - 400 .~ UJ 200 0 C -+- ::y- o ,---... -+-. CD CD -+- 200 '---'" I V 400 '-~ - 600 - 800 - 1000 1200 1400 6600 6800 7000 7200 6300 ---___¿~OO 6700 --....------~ "'-, "- ·"'-........6900 "- \~ 1200 - 1000 - 800 - 600 - 400 ,--..., -+- Q) Q) '+- '---" 200 ..c -+- :J o (f) I V 200 400 - 600 - 800 - 1000 1200 - 1400 ---------.---------- --------------..------------ Phillips Alaska, Inc. - - - -- --- -- -~............., '{ PHILLIPS} . . = ---- -'-",""-" 11. (=- \ ~ - __ ·__n _ -- . ~. .. -- - - --.......---- Created by f¡nc~" uu-u-F~~~uv-i¿-h~~;_~¡ Date plaited: 12-Feb-2DOl ! Plo~ Reference is C01-14 Version#2. ! Coordinates ore in feet reference slot 114. ¡ ¡True Vertical Depths are re:::~c..:. RKB (Doyon 19).\ I ~;;;; I I þ~~ I i - : TNTF.Q Structure: CD#l Well: 14 Field : Alpine Field Location : North Slope, Alaska: East (feet) - > 7000 7400 7800 8000 7200 7600 8200 8400 8600 8800 9000 9200 9400 9600 9800 10000 10200 10400 10600 10800 11000 11200 ~. \:~,8~"", :Il>---,___ -,--._;;~g~-__ - 600 ---\\~~100_______ -.'-~_--_65~~_______~_é7~~'" ill -:: \.. '" 6825 t I \', c-J <..0 5'0 6300 6500 m \', .--- -ID_.....u-u-u-------.___~_.~_~_oo \ 6875 I - '-.. , 6880 J:D _o-4!(~0_ _ _ _ _ _ ~~o~ _ _ _ _ >_~6~2~ _ _ _ _ _ _ ......s~~o_ _ _ _ _ _ -2.5~~ _ _ _ _ _ 5700 5900 \ 6100 6300 6500 "~ 6875 5100 ""'~ 6900 ~ I ~\: \ 6875 \~::o tÐ - 1200 - 1000 .-.-J 800 UJ o C --+- ::J o .,..-..., -+, <D ~ '---" - 200 I V - 400 '" " \\, \\\~ co L/45~u_,J'3; - 600 ;4..::/ ;1.::.+ CA .Y(~ ,~ d¿w.(cr~w<.l( () ì ~,M,. 5Cb' 0 J' - 800 t- ~O'~ ~{,¡~ Oi I fJ&Id ~/r¡rM4:1 1000 AJe/{. ,l ,J1:> - 1200 1400 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 10000 10200 10400 10600 10800 11000 11200 East (feet) -> __~__________________m_____ --------------- Phillips Alaska, Inc. Imë~"~·~-;~~U~~"fi~"~~- m m nummnnm_ 00 _ ______~ For: V Johnson ¡ Slruclure : CD#1 Well : 14 I Date plotted : 12-Feb-2001 North Slope, Alaska I Plot Reference is CD 1 -14 PB1 Versionl2. Field : Alpine Field Locallon : Coordinales ore in feet reference slot 114. True Vertical Depths are reference RKB (Dayon 19).¡ ..:o;¡¡.. .!.iiII__ BJUl.£!! hUGiES TjI,ïEQ East (feet) -> 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 12800 13200 13600 14000 14400 14800 15200 15600 16000 16400 16800 I ~I I - I 0 - 6850 - 0 " 5300 5500 5700 \,68756100 6300 6500 6700 6850 ill . \ 6956 400 ~~ 5900 \ 6890 6;0-; ~ :"Tr - l::ITJ - 400 - 800 \ . 6850 - 800 \ 1200 - - 1200 \ , 1600 - " - 1600 \ " 2000 - \\6890 , - 2000 ,,--... \:::0 \:~~~\\ (j) -+- 0 Q) Q) C '+-- 2400 - - 2400 -+- '-"" ::J ..c ,,--... -+, :J 2800 - - 2800 CD 0 CD Ul \\6890 -+- '-"" I 3200 - - 3200 I V \ V - 'ið\ rm \\\ 3600 - \\,' - 3600 ~ 4000 - \,:900 - 4000 \ 6866 œJ , \ 4400 - " - 4400 , , 4800 - "\ - 4800 till 6875 5200 - ŒJ - 5200 5600 5600 8000 8400 8800 9200 9600 10000 10400 10800 i 1200 11600 12000 12400 12800 13200 13600 14000 14400 14800 15200 15600 16000 16400 16800 East (feet) -> ) ') Phillips Alaska, Inc. CD#1 14 slot #14 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License CDl-14 PB1 Version#2 prop4459 Date printed Date created Last revised 12-Feb-2001 8-Feb-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812,993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#1,14 Your ref CDl-14 PB1 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TANGULA R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R DIN ATE S Deg 1100ft Sect 0.00 0,00 0.00 0,00 0.00 S 0.00 E 0.00 0.00 100.00 0.00 128.00 100.00 0,00 S 0,00 E 0.00 0.00 200.00 0.00 128,00 200.00 0.00 S 0.00 E 0.00 0.00 250.00 0.00 128.00 250.00 0.00 S 0.00 E 0.00 0.00 KOP 350.00 3.00 128.00 349.95 1. 61 S 2.06 E 3.00 2.09 450.00 6.00 128.00 449.63 6.44 S 8.24 E 3.00 8.35 550.00 9.00 128.00 548.77 14.48 S 18.53 E 3.00 18.76 583.33 10.00 128.00 581. 64 17.86 S 22.86 E 3.00 23.15 Begin 4Deg BId 600.00 10.66 128.37 598.04 19.71 S 25.21 E 4.00 25.53 700.00 14.65 129.90 695.59 33.57 S 42.17 E 4.00 42.71 708.78 15.00 130.00 704.08 35.02 S 43.90 E 4.00 44.46 Begin Fnl Trn 800.00 17.76 121. 48 791.60 49.87 S 64.81 E 4.00 65.61 900.00 21,08 114.77 885.91 65.38 S 94.15 E 4.00 95,20 1000.00 24.60 109.87 978.06 80.00 S 130,08 E 4.00 131. 36 1075.58 27.35 106.96 1046.00 90.41 S 161.48 E 4.00 162.93 West Sak 1100.00 28.24 106.14 1067.61 93.65 S 172.40 E 4.00 173.90 1200.00 31. 96 103,21 1154.11 106.28 S 220.92 E 4.00 222.61 1300.00 35.74 100.83 1237.14 11 7.82 S 275.40 E 4.00 277.27 1400.00 39.55 98.86 1316,31 128.21 S 335.57 E 4.00 337.60 1500.00 43.40 97.18 1391.22 137.41 S 401.14 E 4.00 403.31 1600.00 47.26 95.72 1461.51 145.37 S 471.79 E 4.00 474.09 1700.00 51.14 94.44 1526.84 152.05 S 547.18 E 4.00 549.57 1747.43 52.99 93.88 1556.00 154,76 S 584.49 E 4.00 586.92 Permafrost 1800.00 55.03 93.29 1586,89 157.41 S 626.94 E 4.00 629.41 1900.00 58.94 92.24 1641.36 161.44 S 710.68 E 4.00 713.20 2000.00 62.85 91. 28 1690,00 164.11 S 797.99 E 4.00 800.54 2038.18 64.34 90.93 1706.98 164.77 S 832.18 E 4.00 834.74 EOC 2500.00 64.34 90.93 1906,94 171.52 S 1248.41 E 0.00 1251. 03 3000.00 64.34 90.93 2123.44 178.83 S 1699.05 E 0.00 1701.73 3132.94 64.34 90.93 2181.00 180.78 S 1818.87 E 0.00 1821.56 C40 3500.00 64.34 90.93 2339.93 186.14 S 2149.69 E 0.00 2152.43 3638.73 64.34 90.93 2400.00 188.17 S 2274.73 E 0.00 2277.48 9 5/8" Casing pt 3652.59 64.34 90.93 2406.00 188.37 S 2287.22 E 0.00 2289.97 C30 4000.00 64.34 90.93 2556.42 193.45 S 2600.33 E 0.00 2603.13 4484.02 64.34 90.93 2766.00 200.53 S 3036.57 E 0.00 3039.42 C20 4500.00 64.34 90.93 2772.92 200.76 S 3050.97 E 0.00 3053.82 5000.00 64.34 90.93 2989,41 208.07 S 3501.61 E 0.00 3504.52 5500.00 64.34 90.93 3205.91 215.38 S 3952.25 E 0.00 3955.22 6000.00 64.34 90.93 3422.40 222.69 S 4402.89 E 0.00 4405.92 6500.00 64.34 90.93 3638.89 230.00 S 4853.53 E 0.00 4856,62 6816.65 64.34 90,93 3776.00 234.63 S 5138.92 E 0,00 5142.05 K-3 7000.00 64.34 90,93 3855.39 237.32 S 5304.17 E 0.00 5307.32 7394.03 64.34 90.93 4026.00 243.08 S 5659,31 E 0.00 5662.50 K-2 7500.00 64.34 90.93 4071.88 244.63 S 5754.81 E 0.00 5758,02 8000.00 64.34 90.93 4288.38 251.94 S 6205.45 E 0.00 6208.72 8500.00 64.34 90.93 4504,87 259.25 S 6656.09 E 0.00 6659.42 9000.00 64,34 90.93 4721.37 266,56 S 7106.73 E 0.00 7110.12 9500.00 64.34 90.93 4937.86 273.87 S 7557.37 E 0.00 7560.82 10000.00 64,34 90.93 5154.35 281,18 S 8008.01 E 0.00 8011,52 10500.00 64.34 90.93 5370.85 288.49 S 8458.65 E 0,00 8462,22 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11763.18 on azimuth 91.67 degrees from wellhead. Total Dogleg for wellpath is 68.19 degrees. Vertical section is from wellhead on azimuth 90.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ') Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#I,14 Your ref CDl-14 PB1 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 11000.00 64.34 90.93 5587.34 295.80 S 8909.30 E 0.00 8912,92 11500.00 64.34 90.93 5803.84 303.11 S 9359.94 E 0.00 9363.62 11 712.86 64.34 90.93 5896.00 306.22 S 9551.78 E 0.00 9555.49 A1bian-97 12000.00 64.34 90.93 6020.33 310.42 S 9810.58 E 0.00 9814.32 12313.34 64.34 90.93 6156,00 315.00 S 10092.98 E 0.00 10096.76 Albian-96 12500.00 64.34 90.93 6236.82 317.73 S 10261.22 E 0.00 10265.02 12844.53 64.34 90.93 6386.00 322.77 S 10571.73 E 0.00 10575,58 HRZ 13000.00 64.34 90.93 6453.32 325.04 S 10711.86 E 0.00 10715.72 13331.84 64.34 90,93 6597.00 329.89 S 11010.94 E 0.00 11014.84 K-1 13472.01 64,34 90.93 6657,69 331. 94 S 11137.27 E 0.00 11141.19 13500.00 64,34 90.93 6669.81 332.35 S 11162.50 E 0.00 11166.42 13551.25 64.34 90.93 6692.00 333.10 S 11208.69 E 0.00 11212.61 LCU 13791,44 64.34 90.93 6796.00 336,61 S 11425.16 E 0.00 11429.12 Miluveach A 13846.87 64.34 90.93 6820.00 337.42 S 11475.12 E 0.00 11479.08 Alpine D 13888.44 64.34 90.93 6838.00 338.03 S 11512.59 E 0.00 11516.56 Pilot Hole Tgt 13934.63 64.34 90.93 6858.00 338.70 S 11554.22 E 0.00 11558.19 Base Alpine 14000.00 64.34 90.93 6886.31 339.66 S 11613.14 E 0.00 11617.12 14160.96 64.34 90.93 6956.00 342.01 S 11758.21 E 0.00 11762.21 TD All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11763.18 on azimuth 91.67 degrees from wellhead. Total Dogleg for wellpath is 68,19 degrees. Vertical section is from wellhead on azimuth 90.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ') Phillips Alaska, Inc. CD#l,14 Alpine Field,North 5lope, Alaska PROP05AL LI5TING Page 3 Your ref CDl-14 PB1 Version#2 Last revised : 12-Feb-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.00 5 0.00 E KOP 583.33 581.64 17.86 5 22.86 E Begin 4Deg BId 708.78 704.08 35.02 5 43.90 E Begin Fnl Trn 1075.58 1046.00 90.41 5 161.48 E West 5ak 1747.43 1556.00 154.76 5 584.49 E Permafrost 2038.18 1706.98 164,77 5 832.18 E EOC 3132.94 2181.00 180.78 5 1818.87 E C40 3638.73 2400,00 188.17 5 2274.73 E 9 5/8" Casing pt 3652.59 2406.00 188.37 5 2287.22 E C30 4484.02 2766.00 200.53 5 3036.57 E C20 6816.65 3776.00 234.63 5 5138.92 E K-3 7394.03 4026.00 243,08 5 5659.31 E K-2 11712.86 5896.00 306.22 5 9551.78 E Albian-97 12313.34 6156.00 315.00 5 10092.98 E Albian-96 12844.53 6386.00 322.77 5 10571.73 E HRZ 13331.84 6597.00 329.89 5 11010.94 E K-I 13551.25 6692.00 333.10 5 11208.69 E LCU 13791.44 6796.00 336.61 5 11425.16 E Mil uveach A 13846.87 6820.00 337.42 5 11475.12 E Alpine D 13888.44 6838.00 338.03 5 11512.59 E pilot Hole Tgt 13934.63 6858.00 338.70 5 11554.22 E Base Alpine 14160.96 6956.00 342.01 5 11758,21 E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.005 O.OOE 3638.73 2400.00 188.175 2274.73E 9 5/8" Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 6838.00 338.035 11512.59E 12-Feb-2001 ) ') Phillips Alaska, Inc. CD#l 14 slot U4. Alpine Field North Slope, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License CDl-14 PBl Version#2 propU59 Date printed Date created Last revised 12-Feb-2001 8-Feb-2001 l2-Feb-2001 Field is centred on n70 20 37.l00,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 4.6.04.1 Slot location is n70 20 34..004.,w150 55 33.514. Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 24.82.62 E Projection type: alaska - Zone 4., Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#l,14. Your ref CDl-14 PBl Version#2 Alpine Field, North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G R A PHI C Depth Degrees Degrees Depth C 0 o R D I N ATE S Easting Northing C o 0 R D I N ATE S 0,00 0.00 0.00 0.00 0_ OOS O.OOE 385908.00 5975812.99 n70 20 34..00 w150 55 33.51 100.00 0.00 128.00 100.00 O.OOS O.OOE 385908.00 5975812.99 n70 20 34..00 w150 55 33,51 200,00 0.00 128.00 200.00 O.OOS O.OOE 385908.00 5975812,99 n70 20 34..00 w150 55 33.51 250.00 0.00 128.00 250.00 O.OOS O.OOE 385908.00 5975812.99 n70 20 34..00 w150 55 33.51 350.00 450.00 550.00 583.33 600.00 700.00 708.78 800.00 900.00 1000.00 1075.58 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1747.43 1800.00 1900.00 2000.00 2038.18 2500.00 3000.00 3132.94 3500.00 3638.73 3652.59 4000.00 4484.02 4500.00 5000.00 5500.00 6000.00 6500.00 6816.65 7000.00 7394.03 7500.00 8000.00 8500.00 9000.00 9500.00 10000.00 10500.00 6.00 9.00 10.00 10.66 14.65 15.00 17.76 21.08 24.60 27.35 28.24 31.96 35.74 39.55 43.40 47.26 51.14 52.99 55.03 58.94 62.85 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64,34 64.34 64.34 64.34 64.34 64,34 64.34 3.00 128.00 349.95 449.63 548.77 581. 64 598.04 695.59 704.08 791.60 885.91 978.06 1046,00 1067.61 1154,11 1237.14 1316.31 1391.22 95.72 94.44 93.88 93.29 92.24 1461.51 1526.84 1556.00 1586.89 1641.36 ) 1. 618 6.448 14.488 17, 868 19.718 33.578 35.028 49.878 65.388 80.008 90.418 93.658 106.288 117.828 128.218 137.418 145.378 152.058 154.768 157.418 161. 448 164.118 164.778 171.528 178.838 180.788 186.148 188.178 188.378 193.458 200,538 200,768 208.078 215.388 222.698 230.008 234.638 237,328 243,088 244.638 251.948 259.258 266,568 273.878 281.188 288.498 Phillips Alaska, Inc. CD#1 , 14 Alpine Field,North 8lope, Alaska 128.00 128.00 128.00 128 . 37 129.90 130.00 121. 48 114.77 109.87 106.96 106.14 103.21 100.83 98.86 97.18 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 91.28 90.93 90.93 90.93 90.93 1690.00 1706.98 1906.94 2123.44 2181.00 8.24E 18,53E 22.86E 25 , 21E 42,17E 43.90E 64 , 81E 94.15E 130.08E 161. 48E 172.40E 220.92E 275.40E 335.57E 401.14E 471.79E 547,18E 584.49E 626.94E 710,68E 797.99E 832.18E 1248.41E 1699.05E 1818.87E 2149.69E 2274.73E 2287.22E 2600.33E 3036.57E 3050.97E 3501.61E 3952.25E 4402.89E 4853.53E 5138.92E 5304.17E 5659.31E 5754.81E 6205.45E 6656.09E 7106.73E 7557.37E 8008. OlE 8458,65E 2.06E 385910.04 5975811.35 5975806.42 5975798.23 5975794.78 5975792.89 5975778.77 5975777.30 5975762.12 5975746.16 5975730.99 5975720,09 5975716.68 5975703.30 5975690.92 5975679.59 5975669.37 5975660.32 5975652.47 5975649,18 5975645.86 5975640.53 5975636.51 5975635.32 5975622.09 5975607,78 5975603.97 5975593.46 5975589.49 5975589.09 5975579.15 5975565,29 5975564.83 5975550.52 5975536.20 5975521.88 5975507.57 5975498.50 5975493.25 5975481. 97 5975478.94 5975464.62 5975450.30 5975435.99 5975421. 67 5975407,36 5975393.04 n70 20 33.99 n70 20 33.94 n70 20 33.86 n70 20 33.83 n70 20 33.81 n70 20 33.67 n70 20 33.66 n70 20 33.51 n70 20 33.36 n70 20 33.22 n70 20 33,11 n70 20 33.08 n70 20 32.96 n70 20 32.84 n70 20 32.74 n70 20 32.65 n70 20 32.57 n70 20 32.51 n70 20 32.48 n70 20 32.45 n70 20 32.41 ) w150 55 33.45 w150 55 33.27 w150 55 32.97 w150 55 32.85 w150 55 32.78 w150 55 32.28 w150 55 32.23 w150 55 31. 62 w150 55 30.76 w150 55 29.71 w150 55 28.80 w150 55 28.48 w150 55 27.06 w150 55 25.47 w150 55 23.71 w150 55 21. 80 w150 55 19.73 w150 55 17.53 w150 55 16.44 w150 55 15.20 w150 55 12,75 n70 20 32.39 w150 55 10.20 n70 20 32.38 w150 55 09.20 n70 20 32.31 w150 54 57.05 n70 20 32.24 w150 54 43.88 n70 20 32.22 w150 54 40.38 n70 20 32.16 w150 54 30.72 n70 20 32.14 w150 54 27.06 n70 20 32.14 w150 54 26.70 n70 20 32.09 w150 54 17.55 n70 20 32.02 w150 54 04.81 n70 20 32.01 n70 20 31.94 n70 20 31. 86 n70 20 31. 79 n70 20 31.71 w150 54 04.39 w150 53 51.22 w150 53 38.06 w150 53 24.89 w150 53 11. 73 n70 20 31.66 w150 53 03.39 n70 20 31.63 w150 52 58.57 n70 20 31.57 w150 52 48.19 n70 20 31.56 w150 52 45.40 n70 20 31.48 w150 52 32.24 n70 20 31. 40 n70 20 31.33 n70 20 31.25 n70 20 31.17 n70 20 31. 09 w150 52 19.07 w150 52 05.91 w150 51 52.74 w150 51 39.58 w150 51 26.42 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11763.18 on azimuth 91.67 degrees from wellhead. Total Dogleg for we11path is 68.19 degrees. Vertical section is from wellhead on azimuth 90.93 degrees, Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Measured Inclin Depth Degrees 11000.00 11500,00 11712.86 12000.00 12313.34 12500.00 12844.53 13000.00 13331.84 13472.01 13500.00 13551.25 13791. 44 13846.87 13888.44 13934,63 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 90.93 90.93 90.93 90.93 90.93 2339.93 2400.00 2406.00 2556.42 2766,00 90.93 90.93 90.93 90.93 90.93 2772.92 2989.41 3205.91 3422,40 3638.89 90.93 90.93 90.93 90.93 90.93 3776.00 3855.39 4026,00 4071. 88 4288.38 90.93 90.93, 90.93 90.93 90.93 4504.87 4721.37 4937.86 5154.35 5370.85 Azimuth True Vert Degrees Depth 90.93 90.93 90.93 90.93 90,93 5587.34 5803.84 5896.00 6020.33 6156.00 90.93 90,93 90,93 90.93 90.93 6236.82 6386.00 6453.32 6597.00 6657.69 90.93 90.93 90.93 90,93 90.93 6669.81 6692.00 6796.00 6820.00 6838.00 90.93 6858.00 R E C TAN G U L A R COO R DIN ATE 8 295.808 303.118 306.228 310.428 315.008 317.738 322.778 325.048 329.898 331.948 332,358 333.108 336.618 337.428 338.038 338.708 8909.30E 9359.94E 9551.78E 9810.58E 10092,98E 10261. 22E 10571.73E 10711. 86E 11010.94E 11137.27E 11162.50E 11208.69E 11425.16E 11475.12E 11512.59E 385916,14 385926.30 385930.58 385932.90 385949.64 385951. 34 385972.02 386001.12 386036.81 386068.04 386078.91 386127.22 386181. 51 386241. 51 386306.92 386377.43 386452.70 386489.96 386532.36 386616.02 386703.27 386737.45 387153.49 387603.92 387723.69 388054.36 388179.33 388191. 82 388504.79 388940.83 388955.22 389405.66 389856.09 390306.53 390756.96 391042.22 391207.39 391562.36 391657.83 392108.26 392558,70 393009.13 393459.56 393910,00 394360.43 PROP08AL LI8TING Page 2 Your ref CDl-14 PBl Version#2 Last revised: 12-Feb-2001 G RID COO R D 8 Easting Northing 394810,87 395261. 30 395453,06 395711. 73 395994.01 396162.17 396472.54 396612.60 396911. 55 397037.82 397063.04 397109.21 397325.58 397375.52 397412.97 5975378.73 5975364.41 5975358.32 5975350.09 5975341.12 5975335 _ 78 5975325.91 5975321. 46 5975311.96 5975307.95 5975307,15 5975305.68 5975298.80 5975297.22 5975296.03 G E 0 G RAP H I C COO R DIN ATE 8 n70 20 31.01 n70 20 30.94 n70 20 30.90 n70 20 30.86 n70 20 30.81 n70 20 30.78 n70 20 30.72 n70 20 30.70 n70 20 30.64 n70 20 30, 62 n70 20 30.62 n70 20 30.61 n70 20 30.57 n70 20 30,56 n70 20 30.56 w150 51 13.25 w150 51 00.09 w150 50 54.48 w150 50 46.92 w150 50 38.67 w150 50 33.76 w150 50 24.69 w150 50 20.60 w150 50 11.86 w150 50 08.17 w150 50 07.43 w150 50 06.08 w150 49 59.76 w150 49 58.30 w150 49 57.20 11554.22E 397454,58 5975294.70 n70 20 30.55 w150 49 55.99 ') ) 14.000.00 64.34 90.93 6886.31 339.66S 11613.14E 397513.47 5975292.83 n70 20 30.54 w150 49 54.27 14.160.96 64,34 90.93 6956.00 342.01S 11758.21E 397658.47 5975288.23 n70 20 30.51 w150 49 50,03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11763.18 on azimuth 91.67 degrees from wellhead. Total Dogleg for wellpath is 68.19 degrees. Vertical section is from wellhead on azimuth 90.93 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#1,14 Alpine Field, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref CDl-14 PBl Version#2 Last revised : 12-Feb-2001 Comments in wellpath --- - ------ --- - ------ -------------------- MD TVD Rectangular Coords. Comment - - - - - -- - - - --- - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - --- - - - - - - - - - - - - --- - - - -- - - -- - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 250.00 250.00 O.OOS O.OOE KOP 583.33 581. 64 17.86S 22.86E Begin 4Deg BId 708.78 704.08 35.02S 43.90E Begin Fnl Trn 1075,58 1046.00 90.41S 161.48E West Sak 1747.43 1556.00 154.76S 584.49E Permafrost 2038.18 1706.98 164.77S 832.18E EOC 3132.94 2181.00 180.78S 1818.87E C40 3638.73 2400,00 188.17S 2274,73E 9 5/8" Casing pt 3652.59 2406.00 l88.37S 2287.22E C30 4484,02 2766.00 200.53S 3036.57E C20 6816.65 3776,00 234.63S 5138.92E K-3 7394.03 4026.00 243.08S 5659.31E K-2 11712.86 5896.00 306.22S 9551.78E Albian-97 12313,34 6156.00 315.00S 10092.98E Albian-96 12844.53 6386.00 322.77S 10571,73E HRZ 13331.84 6597.00 329.89S 11010.94E K-l 13551,25 6692.00 333,10S 11208.69E LCU 13791. 44 6796.00 336.61S 11425.16E Miluveach A 13846.87 6820.00 337.42S 11475.12E Alpine D 13888.44 6838,00 338.03S 11512.59E pilot Hole Tgt 13934,63 6858.00 338.70S 11554,22E Base Alpine 14160,96 6956.00 342.01S 11758,21E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - -- - - - - - - - - - - - - - - - -- - - - - - -- 0.00 0.00 O.OOS O.OOE 3638.73 2400.00 188.17S 2274.73E 9 5/8" Targets associated with this wellpath ) Target name Geographic Location --- ---- --- -- ----- - -- -- --- - - ---------- --- ---- ----- ------ -- --- -- -- ---- ------ 338.038 Rectangular Coordinates 11512.59E 12-Feb-2001 T.V.D. ) - - --- - - - -- - -- - - - - -- - - - - --- - - -- - - - - - -- - --- - - - - - - -- - -- - - - -- - -- - - -- - - --- - - - -- -- - - - - - - -- - - - - - - - -- - - - - - - - - --- Revised 6838.00 ) Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ ) Your ref Our ref License CDl-14 PBl Version#2 prop4459 Date printed Date created Last revised 12-Feb-2001 8-Feb-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object we11path PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>, ,19A,CD#1 PMSS IFR <564-18590'>, ,17,CD#1 PMSS <10803-13706'>, ,24,CD#1 PMSS <0-9357'>, ,16PHl,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>, ,41PH1,CD#1 PMSS <9081 - 12811'>,,44,CD#1 PMSS <297 - 9882'>,,44PH1,CD#1 PMSS <476 - ll190'>,,34,CD#1 PMSS <0-10897'>, ,3,CD#1 PMSS <0-8350'>, ,26PH1,CD#1 PMSS <7755-11134'>, ,26,CD#1 PMSS <0-8844'>,,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-11608'>, ,42,CD#1 PMSS <0-l0504'>,,5PH1,CD#1 PMSS <9499 - 145l5'>,,5,CD#1 PMSS <0-12921'>, ,43,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <384 - 14477'>,,23,CD#1 PGMS <0-10255'>, ,WD2,CD#1 PMSS <0-7331'>, ,lPH1,CD#1 PMSS <5946 - 10289'>"l,CD#1 PMSS <563-13977'>, ,4,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <565 - 9505'>, ,30PH1,CD#1 PMSS <8965 - 12850'>,,30,CD#1 Reference North is True North Closest approach with 3-D Last revised Distance 6-Apr-2000 49.7 30-Apr-2000 49.7 20-0ct-2000 29.2 7-Aug-2000 99.9 4-Jan-2000 17.2 25-0ct-1999 17.2 3-Apr-2000 269.6 26-Mar-2000 269.6 23-May-2000 300.0 23-May-2000 300.0 11-May-2000 199.8 4-Jan-2000 109,9 6-Mar-2000 120.1 1-Nov-1999 120.1 4-Jan-2000 309.8 16-Nov-1999 309.8 23-Dec-1999 279.9 23-Jan-2000 88.9 23-Jan-2000 88.9 27-0ct-2000 290.2 15-Mar-2000 109.5 29-Aug-2000 74,4 28-Jun-1999 1014.9 29-Feb-2000 129.7 27-Jun-1999 129,7 15-Nov-2000 100.1 16-Mar-2000 129.8 25-Sep-2000 159.9 1-0ct-2000 159.9 Minimum Distance method M.D. 100.0 100.0 350.0 0.0 538.9 538.9 100.0 100.0 100.0 100.0 200.0 294.4 100.0 100.0 200.0 200.0 100.0 327.8 327.8 100.0 294.4 860,0 1550.0 250.0 250.0 100.0 200,0 100,0 100.0 Diverging from M.D. 100.0 100.0 12440.0 0.0 538.9 538.9 100.0 100.0 100.0 100,0 200.0 294.4 100.0 100.0 200.0 200.0 12160,0 327.8 10660.0 100.0 294,4 11020.0 1550.0 250.0 14140.0 9380.0 200.0 100.0 100.0 ) PMSS <473 - 14364'>,,31,CD#1 PMSS <10013' - 14353'>, ,32,CD#1 PMSS <0-11067'>,,32PH1,CD#1 PMSS <0-11693'>,,10,CD#1 PMSS <562 - 12134'>, ,37,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD#1 PMSS <0-12055'>, ,40,CD#1 PMSS <10879 - 11934'>, ,9PH,CD#1 PMSS IFR <0 - 15350'>, ,9,CD#1 PMSS <656 - 7210'>,,28PH1,CD#1 PMSS <6549 - 10468'>, ,28,CD#1 PMSS <507 - 10854'>, ,33,CD#1 PGMS <0 - 8050'>, ,22,CD#1 PMSS <8091 - 8372'>,,22,CD#1 PMSS <8464 - 11500'>,,22A,CD#1 PMSS <472 - 1545'>, ,36PH1,CD#1 PMSS <763 - 7440'>, ,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-13450'>, ,35,CD#1 PMSS <0-12773'>, ,2,CD#1 PMSS <0-12741'>, ,NQ1PH,CD#1 PMSS <10161 - 16118'>, ,29,CD#1 PMSS w/IFR <12632-13308'>, ,6PH,CD#1 PMSS w/IFR <0-16024'>, ,6,CD#1 PMSS <0-11300'>, ,13,CD#1 PMSS <385-8950'>, ,21PH1,CD#1 PMSS <8460 - ???'>,,21,CD#1 27-0ct-2000 14-Dec-2000 4-Jan-2000 8-Dec-2000 26-Aug-1999 13-Feb-2000 14-Feb-2000 4-Jan-2000 22-Sep-1999 5-Sep-2000 18-0ct-2000 18-0ct-2000 17-Dec-2000 22-Dec-2000 5-Jan-2001 13-Nov-2000 13-Nov-2000 13-Nov-2000 4-Jan-2000 4-Jan-2000 22-Dec-1999 24-Jul-2000 24-Jan-2001 19-Jan-2001 31-Jan-2001 8-Feb-2001 8-Feb-2001 27-Sep-2000 12-Feb-2001 12-Feb-2001 168.2 179.7 179.7 39.0 229.9 239.5 239.5 249.8 249,8 259.9 37.5 37.5 137.2 137.2 189.9 80.1 80.1 80.1 220,0 220.0 220.0 209.7 120.1 149.7 149.7 80.3 80.3 9.9 69.6 69.6 583.3 294.4 294.4 405.6 0.0 200.0 200.0 100.0 100.0 100,0 790,9 790.9 372.2 372.2 0.0 100.0 100.0 100.0 100.0 100.0 100.0 100.0 200.0 100.0 100.0 338.9 338.9 100.0 272.2 272.2 ) 583.3 294.4 294.4 6600.0 0.0 200.0 200.0 100.0 100.0 100.0 790.9 11840.0 372.2 372 .2 272,2 13820,0 13820.0 13820.0 100.0 100.0 100.0 100,0 12340.0 100.0 100.0 338.9 13540.0 8040.0 13560.0 13560.0 ) ) Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref Our ref License CDl-14 PBl Version#2 prop4459 Date printed Date created Last revised 12-Feb-2001 8-Feb-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) '} Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#l,14 Your ref CDl-14 PB1 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 128,00 100.00 0.00 S 0.00 E 0.00 0.48 0.48 0.26 N/A 200.00 0.00 128.00 200.00 0,00 S 0.00 E 0.00 0.96 0.96 0,52 N/A 250.00 0.00 128,00 250,00 0.00 S 0.00 E 0.00 1.19 1.19 0.65 N/A 350.00 3.00 128.00 349.95 1. 61 S 2.06 E 2.09 1. 90 1. 67 0.90 38.00 450.00 6.00 128.00 449.63 6,44 S 8.24 E 8.35 2.80 2.16 1.17 38.00 550.00 9.00 128.00 548.77 14.48 S 18,53 E 18.76 3.76 2.65 1. 45 38.00 583.33 10.00 128,00 581.64 17.86 S 22.86 E 23.15 4.08 2.82 1. 55 38.00 600.00 10.66 128.37 598.04 19.71 S 25,21 E 25.53 4.24 2.90 1. 60 38,02 700.00 14.65 129.90 695.59 33.57 S 42.17 E 42.71 5.21 3.44 1.92 38.41 708.78 15.00 130.00 704.08 35.02 S 43,90 E 44,46 5.29 3.48 1. 95 38.44 800.00 17.76 121.48 791.60 49.87 S 64.81 E 65.61 6.17 4.00 2.28 37.39 900.00 21. 08 114.77 885.91 65.38 S 94.15 E 95.20 7.11 4.63 2.68 35.77 1000.00 24.60 109.87 978.06 80.00 S 130.08 E 131. 36 8.02 5.34 3.12 34.28 1075.58 27.35 106.96 1046.00 90.41 S 161. 48 E 162.93 8.70 5.97 3.49 33,53 1100.00 28.24 106.14 1067.61 93.65 S 172.40 E 173.90 8.91 6.18 3.61 33.28 1200.00 31.96 103.21 1154.11 106.28 S 220.92 E 222.61 9.79 7.16 4.16 33.23 1300.00 35.74 100,83 1237.14 11 7.82 S 275.40 E 277.27 10.65 8.35 4.75 35.05 1400.00 39.55 98.86 1316.31 128.21 S 335.57 E 337.60 11.56 9.73 5.40 41. 44 1500.00 43.40 97.18 1391,22 137.41 S 401.14 E 403.31 12.70 11.18 6.11 58.81 1600.00 47.26 95.72 1461.51 145.37 S 471.79 E 474.09 14.55 12.30 6.86 79.60 1700.00 51.14 94.44 1526.84 152.05 S 547.18 E 549,57 17.16 13.11 7.66 88.73 1747.43 52.99 93.88 1556.00 154.76 S 584.49 E 586.92 18.72 13.43 8.06 90.30 1800.00 55.03 93.29 1586.89 157.41 S 626.94 E 629.41 20.45 13.78 8.50 92.05 1900.00 58.94 92.24 1641. 36 161.44 S 710.68 E 713.20 24.51 14.38 9.38 93.22 2000.00 62.85 91. 28 1690,00 164.11 S 797.99 E 800.54 29.47 14.92 10.30 93.47 2038.18 64,34 90.93 1706.98 164.77 S 832.18 E 834.74 31.54 15.11 10.66 93.45 2500.00 64.34 90.93 1906.94 171 . 52 S 1248.41 E 1251. 03 57.17 17.50 15.00 92.76 3000.00 64,34 90.93 2123.44 178.83 S 1699.05 E 1701. 73 85.38 20.09 19.67 92.27 3132.94 64.34 90.93 2181.00 180.78 S 1818.87 E 1821. 56 92.92 20.78 20.90 92.19 3500.00 64.34 90.93 2339.93 186.14 S 2149,69 E 2152.43 113.73 22.67 24.32 91. 98 3638.73 64.34 90.93 2400,00 188.17 S 2274.73 E 2277.48 121. 61 23.38 25.61 91.93 3652.59 64.34 90.93 2406.00 188.37 S 2287.22 E 2289.97 122.40 23.45 25,74 91.92 4000.00 64.34 90.93 2556.42 193.45 S 2600.33 E 2603,13 142.13 25.23 28.96 91. 79 4484.02 64.34 90.93 2766.00 200.53 S 3036.57 E 3039.42 169.66 27.70 33.45 91. 66 4500.00 64.34 90.93 2772.92 200.76 S 3050.97 E 3053.82 170.57 27.78 33.60 91. 66 5000.00 64.34 90.93 2989.41 208.07 S 3501.61 E 3504.52 199.02 30.32 38.24 91. 56 5500.00 64.34 90.93 3205.91 215.38 S 3952.25 E 3955.22 227,48 32.86 42.87 91. 49 6000.00 64.34 90.93 3422.40 222,69 S 4402.89 E 4405.92 255.94 35.39 47.51 91.43 6500.00 64.34 90.93 3638.89 230.00 S 4853.53 E 4856.62 284.41 37,91 52.14 91. 38 6816.65 64.34 90.93 3776.00 234.63 S 5138.92 E 5142.05 302,44 39.51 55.07 91. 35 7000,00 64.34 90.93 3855.39 237,32 S 5304.17 E 5307.32 312.88 40.44 56.77 91. 34 7394.03 64.34 90.93 4026.00 243.08 S 5659.31 E 5662.50 335.33 42.42 60,42 91.31 7500.00 64.34 90.93 4071.88 244.63 S 5754.81 E 5758.02 341. 36 42.95 61. 40 91. 31 8000.00 64.34 90,93 4288.38 251.94 S 6205.45 E 6208.72 369.84 45.47 66.03 91. 28 8500.00 64.34 90.93 4504.87 259.25 S 6656.09 E 6659.42 398,32 47,98 70.66 91. 26 9000.00 64.34 90,93 4721.37 266,56 S 7106.73 E 7110,12 426.80 50.50 75.29 91.23 9500.00 64.34 90,93 4937.86 273.87 S 7557.37 E 7560.82 455.28 53,01 79.93 91. 22 10000.00 64.34 90.93 5154.35 281.18 S 8008.01 E 8011.52 483.77 55.52 84.55 91. 20 10500.00 64.34 90.93 5370.85 288,49 S 8458.65 E 8462.22 512.25 58.02 89.18 91.18 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 11763,18 on azimuth 91,67 degrees from wellhead. Vertical section is from wellhead on azimuth 90.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) Phillips Alaska, Inc. CD#1,14 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 11000.00 11500.00 11712.86 12000.00 12313.34 12500.00 12844.53 13000,00 13331.84 13472.01 13500.00 13551.25 13791.44 13846.87 13888,44 13934.63 14000.00 14160.96 64.34 64.34 64,34 64.34 64.34 90.93 90.93 90.93 90.93 90.93 5587.34 5803,84 5896.00 6020.33 6156.00 6236.82 6386.00 6453.32 6597.00 6657.69 6669.81 6692,00 6796.00 6820.00 6838.00 6858.00 6886.31 6956.00 Survey Tool ) PROPOSAL LISTING Page 2 Your ref CDl-14 PB1 Version#2 Last revised : 12-Feb-2001 R E C TAN G U L A R COO R DIN ATE S 295.80 S 303,11 S 306.22 S 310.42 S 315.00 S 317.73 S 322.77 S 325.04 S 329.89 S 331. 94 S 332.35 S 333.10 S 336.61 S 337.42 S 338.03 S 338.70 S 339.66 S 342.01 S Vert Sect 8909.30 E 8912.92 9359.94 E 9363.62 9551.78 E 9555.49 9810.58 E 9814.32 10092.98 E 10096.76 10261.22 E 10265.02 10571.73 E 10575.58 10711.86 E 10715.72 11010.94 E 11014.84 11137.27 E 11141.19 11162.50 E 11166.42 11208.69 E 11212.61 11425.16 E 11429,12 11475.12 E 11479.08 11512.59 E 11516,56 11554.22 E 11558.19 11613.14 E 11617.12 11758.21 E 11762.21 POSITION UNCERTAINTY SUMMARY ------------------------------ ------------------------------ Ellipse Semi Axes Minor Major Minor Vert. Azi. 540.73 569.22 581.35 597.70 615.55 626.19 645.82 654.68 673.58 681.57 683.16 686.08 699.77 702.92 705.29 707.92 711.65 720.82 Error Model 60.53 63.04 64.10 65.54 67.11 68.05 69.77 70.55 72.21 72.91 73.05 73.31 74.51 74,79 75.00 75.23 75.55 76.36 93.81 98.44 100.41 103.07 105.97 107.70 110.89 112.33 115.40 116.70 116.96 11 7.43 119.66 120.17 120.56 120.98 121. 59 123.08 91.17 91.16 91.15 91.15 91.14 91.14 91.13 91.13 91.12 91.12 91.12 91.12 91.12 91.12 91.12 91.12 91. 11 91. 11 Position Uncertainty Major Minor Vert. ---------------------------------------------------------------------------------------------------- 64.34 64.34 64.34 64.34 64.34 90.93 90.93 90.93 90.93 90.93 14161 MWD + IFR (Alaska) - Corrected Dat User speci fied 1, Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5, Surface position uncertainty is not included, 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. 64.34 64,34 64.34 64.34 64.34 90.93 90.93 90.93 90,93 90.93 64.34 64.34 64.34 90.93 90.93 90.93 Depth From To o 720.83 76.36 123.08 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level), Bottom hole distance is 11763,18 on azimuth 91.67 degrees from wellhead. Vertical section is from wellhead on azimuth 90.93 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ') Phillips Alaska, Inc. CD#1,14 Alpine Field/North Slope, Alaska PROPOSAL LISTING Page 3 Your ref CDl-14 PB1 version#2 Last revised : 12-Feb-2001 Comments in we1lpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 250.00 250,00 0.00 S 0.00 E KOP 583.33 581.64 17.86 S 22.86 E Begin 4Deg BId 708.78 704.08 35.02 S 43.90 E Begin Fnl Trn 1075.58 1046.00 90.41 S 161. 48 E West Sak 1747.43 1556.00 154.76 S 584.49 E Permafrost 2038.18 1706.98 164.77 S 832.18 E EOC 3132.94 2181.00 180.78 S 1818.87 E C40 3638.73 2400.00 188.17 S 2274.73 E 9 5/8" Casing pt 3652.59 2406.00 188.37 S 2287.22 E C30 4484.02 2766.00 200.53 S 3036.57 E C20 6816.65 3776.00 234.63 S 5138.92 E K-3 7394.03 4026.00 243.08 S 5659.31 E K-2 11712.86 5896.00 306.22 S 9551.78 E Albian-97 12313.34 6156.00 315.00 S 10092.98 E Albian-96 12844.53 6386.00 322.77 S 10571.73 E HRZ 13331.84 6597.00 329.89 S 11010.94 E K-1 13551.25 6692.00 333.10 S 11208.69 E LCU 13791.44 6796.00 336.61 S 11425.16 E Miluveach A 13846,87 6820.00 337.42 S 11475.12 E Alpine D 13888.44 6838.00 338.03 S 11512.59 E Pilot Hole Tgt 13934.63 6858.00 338.70 S 11554.22 E Base Alpine 14160.96 6956.00 342.01 S 11758.21 E TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0,00 O.OOS O.OOS O.OOE 3638.73 2400.00 O.OOE 14168.90 6956.00 188,17S 342,01S 2274.73E 9 5/8" 11758.21E 7" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 6838.00 338.03S 11512.59E 12-Feb-2001 ) ) Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License CDl-14 Version#2 prop4423 Date printed Date created Last revised 12-Feb-200l 17-Jan-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ') Phillips Alaska, Inc, PROPOSAL LISTING Page 1 CD#1,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R DIN ATE S Degl100ft Sect 0.00 0.00 0.00 0.00 0,00 S 0.00 E 0.00 0.00 100.00 0.00 128.00 100.00 0.00 S 0.00 E 0.00 0.00 200.00 0.00 128.00 200.00 0.00 S 0.00 E 0.00 0.00 250.00 0.00 128.00 250.00 0.00 S 0.00 E 0.00 0.00 KOP 350.00 3.00 128.00 349.95 1. 61 S 2.06 E 3.00 2.39 450.00 6.00 128.00 449.63 6.44 S 8.24 E 3.00 9.56 550.00 9.00 128.00 548.77 14.48 S 18.53 E 3,00 21.48 583.33 10.00 128.00 581.64 17.86 S 22.86 E 3,00 26,51 Begin 4Deg BId 600.00 10,66 128.37 598.04 19.71 S 25.21 E 4.00 29.24 700.00 14.65 129.90 695.59 33.57 S 42.17 E 4.00 49.45 708.78 15.00 13 0 . 00 704,08 35.02 S 43.90 E 4.00 51. 53 Begin Fnl Trn 800.00 17.76 121.48 791.60 49.87 S 64.81 E 4.00 74.47 900.00 21. 08 114.77 885,91 65.38 S 94.15 E 4.00 101,94 1000.00 24.60 109.87 978.06 79.99 S 130.08 E 4.00 131.71 1075.57 27.35 106.96 1046.00 90.41 S 161.48 E 4,00 155.65 West Sak 1100.00 28.24 106.14 1067.61 93.65 S 172.40 E 4.00 163.64 1200.00 31. 96 103.21 1154.11 106.28 S 220.92 E 4.00 197.58 1300.00 35.74 100.83 1237.14 11 7.82 S 275.40 E 4.00 233,35 1400.00 39.55 98.86 1316.31 128,21 S 335.57 E 4.00 270.78 1500.00 43.40 97.18 1391.22 137.41 S 401,14 E 4.00 309.70 1600,00 47.26 95.72 1461.51 145.37 S 471.79 E 4,00 349.90 1700.00 51.14 94.44 1526.84 152.04 S 547.18 E 4.00 391.20 1747.43 52.99 93.88 1556.00 154.76 S 584.49 E 4.00 411.12 Permafrost 1800.00 55.03 93.29 1586.89 157.41 S 626.94 E 4.00 433.40 1900,00 58,94 92.24 1641.37 161.44 S 710.68 E 4.00 476.28 2000.00 62.85 91. 28 1690.00 164,11 S 797.99 E 4.00 519.64 2038.18 64.34 90.93 1706.98 164.77 S 832.18 E 4.00 536.28 EOC 2500.00 64.34 90.93 1906.94 171 . 52 S 1248.41 E 0.00 737.71 3000.00 64.34 90.93 2123.44 178.83 S 1699.05 E 0.00 955.80 3132.94 64.34 90.93 2181.00 180.77 S 1818.87 E 0,00 1013,79 C40 3500.00 64.34 90.93 2339.93 186,14 S 2149.69 E 0.00 1173.89 3638.73 64.34 90.93 2400.00 188,17 S 2274.72 E 0,00 1234,40 9 5/8" Casing pt 3652.59 64,34 90.93 2406.00 188.37 S 2287.21 E 0.00 1240.44 C30 4000.00 64.34 90.93 2556.42 193.45 S 2600.33 E 0.00 1391. 97 4484.02 64.34 90.93 2766.00 200.53 S 3036.57 E 0.00 1603,09 C20 4500.00 64.34 90.93 2772.92 200.76 S 3050.97 E 0.00 1610.06 5000.00 64.34 90.93 2989,41 208.07 S 3501.61 E 0.00 1828.15 5500.00 64.34 90.93 3205.91 215.38 S 3952.25 E 0.00 2046.23 6000.00 64.34 90.93 3422.40 222.69 S 4402.89 E 0.00 2264.32 6500.00 64,34 90.93 3638.89 230.00 S 4853.53 E 0.00 2482,40 6816.65 64.34 90.93 3776.00 234.63 S 5138.92 E 0,00 2620.52 K-3 7000.00 64.34 90,93 3855.39 237.31 S 5304.17 E 0.00 2700.49 7394.03 64.34 90.93 4026.00 243.08 S 5659.31 E 0.00 2872.36 K-2 7500.00 64.34 90.93 4071.88 244.63 S 5754.81 E 0.00 2918.58 8000.00 64.34 90.93 4288.38 251.94 S 6205.45 E 0.00 3136.66 8500.00 64.34 90.93 4504.87 259.25 S 6656.09 E 0.00 3354.75 9000.00 64.34 90.93 4721.37 266,56 S 7106.73 E 0.00 3572.84 9500.00 64.34 90.93 4937.86 273.87 S 7557.37 E 0,00 3790,92 10000.00 64,34 90.93 5154.35 281.18 S 8008,01 E 0.00 4009.01 10500.00 64.34 90.93 5370.85 288.49 S 8458.66 E 0.00 4227.10 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Total Dogleg for wellpath is 134.02 degrees. Vertical section is from S 0,00 E 0.00 on azimuth 151.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ') Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#1,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TANGULA R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R DIN ATE S Deg/l00ft Sect 11000.00 64.34 90.93 5587.34 295.80 S 8909.30 E 0.00 4445.18 11500.00 64.34 90.93 5803.84 303.11 S 9359.94 E 0.00 4663.27 11712.86 64,34 90.93 5896.00 306.22 S 9551. 78 E 0.00 4756.11 Albian-97 12000.00 64.34 90.93 6020.33 310.42 S 9810.58 E 0.00 4881,36 12313,34 64.34 90.93 6156,00 315.00 S 10092.98 E 0.00 5018.03 Albian-96 12500.00 64.34 90.93 6236.82 317.73 S 10261.22 E 0.00 5099.44 12844.53 64.34 90.93 6386.00 322.77 S 10571.73 E 0.00 5249.72 HRZ 13 000.00 64.34 90.93 6453.32 325.04 S 10711. 86 E 0.00 5317.53 13334.15 64.34 90.93 6598.00 329.93 S 11013.02 E 0.00 5463.28 K_l 13472.01 64.34 90.93 6657.69 331.94 S 11137.27 E 0.00 5523.41 Begin Fnl Bld/Trn 13500.00 64.83 93.67 6669.71 332.96 S 11162.53 E 9.00 5536.17 13555.89 65.94 99.06 6693.00 338.60 S 11213.00 E 9.00 5564.85 LCU 13600.00 66.96 103,25 6710.63 346.42 S 11252.66 E 9.00 5590.38 13700.00 69.64 112.50 6747.67 374.97 S 11340.93 E 9.00 5657.04 13800.00 72.80 121.40 6779,92 417,88 S 11425.18 E 9.00 5734,49 13869.15 75.20 127.37 6799.00 455.42 S 11479,99 E 9.00 5793.37 Miluveach A 13900.00 76.33 129.99 6806.59 474.11 S 11503.33 E 9.00 5820.83 13977.57 79.27 136.47 6823.00 526.02 S 11558.51 E 9.00 5892.58 Alpine D 14000.00 80.14 138.32 6827.01 542.26 S 11573.45 E 9.00 5913.94 14100.00 84.16 146.45 6840.68 620.68 S 11633.82 E 9.00 6011.51 14168.91 87.00 151.98 6846.00 679.68 S 11668.96 E 9.00 6080.10 Tgt/7 "Csgpt 14168.93 87.00 151.99 6846.00 679.69 S 11668.97 E 9,00 6080.12 CDl-14 TgtCstPt Rvsd 8-Jan-Ol 14268.93 88.00 151.99 6850.36 767.89 S 11715.89 E 1. 00 6180.03 14368.93 89.00 151.99 6852.98 856.14 S 11762.84 E 1. 00 6279.99 14449.43 89.81 151. 99 6853.82 927.21 S 11800.65 E 1. 00 6360.48 Fnl EOB 14500.00 89.81 151. 99 6853.99 971.85 S 11824.40 E 0.00 6411. 06 14600.00 89.81 151.99 6854,33 1060.13 S 11871.37 E 0.00 6511.05 14700.00 89.81 151. 99 6854.67 1148.42 S 11918.34 E 0.00 6611.05 14800.00 89.81 151.99 6855.00 1236.70 S 11965.31 E 0.00 6711. 05 14900.00 89.81 151. 99 6855.34 1324.98 S 12012.28 E 0.00 6811.05 15000.00 89.81 151. 99 6855.67 1413.26 S 12059.25 E 0.00 6911.05 15097.56 89.81 151. 98 6856.00 1499.39 S 12105.07 E 0.00 7008.62 Base Alpine 15100.00 89.81 151. 98 6856.01 1501.55 S 12106.22 E 0.00 7011.05 15200.00 89.81 151. 98 6856.34 1589.83 S 12153.19 E 0.00 7111. 05 15300.00 89.81 151.98 6856.68 1678.11 S 12200.16 E 0.00 7211.05 15400.00 89,81 151.98 6857.02 1766.39 S 12247.12 E 0.00 7311.05 15500.00 89.81 151. 98 6857.35 1854,67 S 12294.09 E 0.00 7411.05 15600.00 89.81 151. 98 6857.69 1942,96 S 12341.06 E 0.00 7511.05 15700.00 89.81 151. 98 6858,03 2031.24 S 12388.03 E 0.00 7611.05 15800.00 89.81 151.98 6858.36 2119.52 S 12435.00 E 0.00 7711.05 15900.00 89.81 151.98 6858.70 2207.80 S 12481.97 E 0.00 7811.05 16000.00 89.81 151.98 6859.04 2296.09 S 12528.94 E 0.00 7911.05 16100.00 89.81 151. 98 6859,37 2384.37 S 12575.91 E 0.00 8011.05 16200.00 89.81 151.98 6859,71 2472.65 S 12622.88 E 0.00 8111.05 16300.00 89.81 151.98 6860.05 2560.93 S 12669.85 E 0.00 8211.05 16400.00 89.81 151.98 6860.38 2649.22 S 12716.82 E 0.00 8311. 04 16500.00 89.81 151.98 6860.72 2737.50 S 12763.79 E 0.00 8411. 04 16600,00 89.81 151. 98 6861. 06 2825.78 S 12810.76 E 0.00 8511.04 16700.00 89.81 151. 98 6861.39 2914.06 S 12857.73 E 0.00 8611.04 16800,00 89.81 151.98 6861.73 3002.34 S 12904.70 E 0,00 8711,04 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Total Dogleg for wellpath is 134.02 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 151.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ') Phillips Alaska, Inc. PROPOSAL LISTING Page 3 CD#1,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C T AN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I NA T E S Deg/100ft Sect 16900.00 89.81 151.98 6862.07 3090.63 S 12951.67 E 0.00 8811. 04 17000.00 89,81 151. 98 6862,40 3178.91 S 12998.63 E 0.00 8911. 04 17100.00 89.81 151.98 6862.74 3267.19 S 13045.60 E 0.00 9011. 04 17200.00 89.81 151.98 6863.07 3355,47 S 13092.57 E 0.00 9111. 04 17300.00 89.81 151. 98 6863.41 3443.76 S 13139.54 E 0.00 9211.04 17400.00 89.81 151. 98 6863.75 3532.04 S 13186,51 E 0,00 9311. 04 17500.00 89.81 151. 98 6864.08 3620.32 S 13233.48 E 0.00 9411.04 17600.00 89.81 151.98 6864.42 3708.60 S 13280.45 E 0.00 9511. 04 17700.00 89.81 151.98 6864.76 3796.89 S 13327.42 E 0.00 9611. 04 17800.00 89.81 151.98 6865.09 3885.17 S 13374.39 E 0.00 9711.04 17900.00 89.81 151. 98 6865.43 3973.45 S 13421.36 E 0.00 9811,04 18000.00 89.81 151. 98 6865.77 4061.73 S 13468.33 E 0.00 9911. 04 18069.28 89.81 151. 98 6866,00 4122.89 S 13500.87 E 0.00 9980.32 Tgt/lntrmdPt 18069.30 89.81 151. 98 6866.00 4122.92 S 13500.88 E 0.00 9980.34 CDl-14 TgtIntrmdPt 8-Feb-01 18098.34 89.52 151.99 6866.17 4148.55 S 13514.52 E 1. 00 10009.38 End Angle Drop 18500.00 89.52 151.99 6869.54 4503.14 S 13703.15 E 0.00 10411. 02 19000.00 89.52 151. 99 6873.74 4944.56 S 13937.96 E 0.00 10911.00 19269.36 89.52 151. 99 6876.00 5182.35 S 14064.46 E 0.00 11180.35 TD 19269.38 89.52 151. 99 6876.00 5182.37 S 14064.47 E 0.01 11180.37 CD1-14 TgtTD Rvsd 8-Feb-Ol All data is in feet unless otherwise stated, Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead, Total Dogleg for wellpath is 134.02 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 151,99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) Phillips Alaska, Inc. CD#l,14 Alpine Field,North 51ope, Alaska MD TVD Rectangular Coords. ) PROP05AL LI5TING Page 4 Your ref CDl-14 Version#2 Last revised : 12-Feb-2001 Comments in wellpath -------------------- -------------------- Comment ----------------------------------------------------------------------------------------------------------- 250.00 583.33 708.78 1075.57 1747.43 2038.18 3132.94 3638.73 3652.59 4484.02 6816.65 7394.03 11712.86 12313.34 12844.53 13334.15 13472.01 13555.89 13869.15 13977.57 14168.91 14168.93 14449.43 15097.56 18069.28 18069.30 18098.34 19269.36 19269.38 250.00 581.64 704.08 1046.00 1556.00 1706.98 2181.00 2400.00 2406.00 2766.00 3776.00 4026.00 5896.00 6156.00 6386.00 6598.00 6657.69 6693.00 6799.00 6823.00 6846.00 6846.00 6853.82 6856.00 6866.00 6866.00 6866.17 6876.00 6876.00 Top MD Top TVD 0.00 5 17.86 5 35.02 5 90.41 5 154.76 5 164.77 5 180.77 5 188.17 5 188.37 5 200.53 5 234.63 5 243.08 5 306.22 5 315.00 5 322.77 5 329.93 5 331. 94 5 338,60 5 455.42 5 526.02 5 679.68 5 679.69 5 927.21 5 1499.39 5 4122.89 5 4122.92 5 4148.55 5 5182.35 5 5182.37 5 0.00 E 22.86 E 43.90 E 161. 48 E 584.49 E 832.18 E 1818.87 E 2274.72 E 2287.21 E 3036.57 E 5138.92 E 5659.31 E 9551. 78 E 10092.98 E 10571.73 E 11013.02 E 11137.27 E 11213.00 E 11479.99 E 11558.51 E 11668.96 E 11668.97 E 11800.65 E 12105.07 E 13500.87 E 13500.88 E 13514.52 E 14064.46 E 14064.47 E 0.005 Rectangular Coords. O.OOE 3638.73 2400.00 188.175 Rectangular Coords. 2274.72E 9 5/8" KOP Begin 4Deg Bld Begin Fnl Trn West 8ak Permafrost EOC C40 9 5/8" Casing pt C30 C20 K-3 K-2 Albian-97 Albian-96 HRZ K_1 Begin Fnl Bld/Trn LCU Miluveach A Alpine D Tgt/7 "Csgpt CDl-14 TgtCstPt Rvsd 8-Jan-01 Fnl EOB Base Alpine Tgt/ In trmdpt CDl-14 TgtIntr.mdPt 8-Feb-01 End Angle Drop TD CDl-14 TgtTD Rvsd 8-Feb-01 Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD ----------------------------------------------------------------------------------------------------------- Casing Target name 0.00 0.00 Geographic Location Targets associated with this wellpath T.V.D. Rectangular Coordinates ------------------------------------- ------------------------------------- ----------------------------------------------------------------------------------------------------------- Revised CDl-14 TgtCstPt Rvsd 397564.000,5974952.000,0.0000 CDl-14 TgtIntr.mdPt 8 399342.000,5971481.000,2.0000 CDl-14 TgtTD Rvsd 8 399889.000,5970413.000,0.0000 6846.00 6866.00 6876.00 679.698 4122.928 5182.378 11668.97E 13500.88E 14064.47E 17-Jan-2001 17-Jan-2001 8-Feb-2001 ) ) Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License CDl-14 Version#2 prop4423 Date printed Date created Last revised l2-Feb-2001 17-Jan-200l 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#1,14 Your ref CDl-14 Version#2 Alpine Fie1d,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COO R D S G E 0 G RAPHIC Depth Degrees Degrees Depth C o 0 RDINATES Easting Northing C 0 0 R DIN ATE S 0.00 0.00 0.00 0.00 O.OOS O,OOE 385908.00 5975812.99 n70 20 34.00 w150 55 33.51 100.00 0.00 128. 00 100.00 O.OOS O.OOE 385908.00 5975812.99 n70 20 34.00 w150 55 33.51 200.00 0.00 128 . 00 200.00 O.OOS O.OOE 385908,00 5975812,99 n70 20 34.00 w150 55 33.51 250.00 0.00 128.00 250.00 O.OOS O.OOE 385908.00 5975812.99 n70 20 34.00 w150 55 33.51 350.00 450.00 550.00 583.33 600.00 700.00 708.78 800.00 900.00 1000.00 1075.57 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1747.43 1800,00 1900.00 2000.00 2038.18 2500.00 3000.00 3132.94 3500.00 3638.73 3652.59 4000.00 4484.02 4500.00 5000.00 5500,00 6000.00 6500.00 6816.65 7000.00 7394.03 7500.00 8000.00 8500.00 9000.00 9500.00 10000,00 10500,00 3.00 128,00 349.95 449.63 548.77 581. 64 598,04 695.59 704.08 791.60 885.91 978.06 1046.00 1067.61 1154.11 1237.14 1316.31 1391.22 95.72 94.44 93.88 93.29 92.24 1461.51 1526.84 1556.00 1586.89 1641.37 ') 1. 615 6.445 14.485 17.865 19.715 33.575 35.028 49.878 65.385 79.995 90.418 93.658 106.288 117.828 128,218 137.418 145.378 152,048 154.768 157.418 161.448 164.118 164.778 171.528 178,838 180.778 186,148 188.178 188.378 193.458 200.535 200.768 208.075 215.388 222.698 230.008 234.635 237.318 243.088 244.638 251.945 259.258 266,568 273.878 281.188 288.498 Phillips Alaska, Inc. CD#l,14 Alpine Field, North 81ope, Alaska 6.00 9.00 10.00 10.66 14.65 128.00 128.00 128.00 128.37 129.90 91.28 90.93 90.93 90.93 90.93 1690.00 1706.98 1906.94 2123.44 2181. 00 8.24E 18.53E 22.86E 25.21E 42.17E 43.90E 64.81E 94.15E 130.08E 161.48E 172.40E 220.92E 275,40E 335.57E 401.14E 471.79E 547.18E 584.49E 626.94E 710.68E 797.99E 832.18E 1248.41E 1699.05E 1818.87E 2149.69E 2274.72E 2287.21E 2600.33E 3036.57E 3050.97E 3501.61E 3952.25E 4402.89E 4853.53E 5138.92E 5304.17E 5659.31E 5754.81E 6205.45E 6656.09E 7106.73E 7557.37E 8008. OlE 8458,66E Measured Inclin Azimuth True Vert R E C TAN G U L A R Depth Degrees Degrees Depth COO R DIN ATE 8 11000.00 11500.00 11712.86 12000.00 12313.34 12500.00 12844.53 13000.00 13334.15 13472,01 13500.00 13555,89 13600.00 13700.00 13800.00 13869.15 15.00 17.76 21. 08 24.60 27.35 130.00 121. 48 114.77 109.87 106,96 28,24 31.96 35.74 39.55 43.40 106.14 103.21 100.83 98.86 97.18 47.26 51.14 52,99 55.03 58.94 62.85 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 90.93 90.93 90.93 90.93 90.93 2339.93 2400.00 2406.00 2556.42 2766.00 2.06E 385910.04 5975811.35 5975806.42 5975798.23 5975794,78 5975792.89 5975778.77 5975777,30 5975762.12 5975746.16 5975730,99 5975720.09 5975716.68 5975703.30 5975690.92 5975679.59 5975669.37 5975660.32 5975652.47 5975649.18 5975645.87 5975640.54 5975636.51 5975635.32 5975622.10 5975607.78 5975603.97 5975593.46 5975589.49 5975589.10 5975579,15 5975565,29 5975564.83 5975550.52 5975536.20 5975521. 88 5975507,57 5975498.50 5975493.25 5975481. 97 5975478.94 5975464.62 5975450.30 5975435.99 5975421.67 5975407,36 5975393.04 ) n70 20 33,99 n70 20 33.94 n70 20 33.86 n70 20 33.83 n70 20 33.81 n70 20 33.67 w150 55 33.45 w150 55 33.27 w150 55 32,97 w150 55 32.85 w150 55 32,78 w150 55 32,28 n70 20 33,66 w150 55 32.23 n70 20 33,51 w150 55 31.62 n70 20 33,36 w150 55 30.76 n70 20 33.22 w150 55 29.71 n70 20 33.11 w150 55 28.80 n70 20 33.08 n70 20 32.96 n70 20 32.84 n70 20 32.74 n70 20 32.65 n70 20 32.57 n70 20 32.51 n70 20 32.48 n70 20 32.45 n70 20 32.41 n70 20 32,39 n70 20 32.38 n70 20 32.31 n70 20 32.24 n70 20 32.22 n70 20 32.16 n70 20 32.14 n70 20 32.14 n70 20 32.09 n70 20 32.02 n70 20 32.01 n70 20 31.94 n70 20 31. 86 n70 20 31.79 n70 20 31.71 n70 20 31. 66 n70 20 31.63 n70 20 31. 57 n70 20 31.56 n70 20 31.48 n70 20 31.40 n70 20 31. 33 n70 20 31.25 n70 20 31.17 n70 20 31. 09 w150 55 28,48 w150 55 27.06 w150 55 25.47 w150 55 23.71 w150 55 21. 80 w150 55 19.73 w150 55 17.53 w150 55 16.44 w150 55 15.20 w150 55 12,75 w150 55 10.20 w150 55 09.21 w150 54 57,05 w150 54 43.88 w150 54 40.38 w150 54 30.72 w150 54 27.06 w150 54 26.70 w150 54 17.55 w150 54 04.81 w150 54 04.39 w150 53 51.22 w150 53 38.06 w150 53 24.89 w150 53 11. 73 w150 53 03,39 w150 52 58.57 w150 52 48.19 w150 52 45.40 w150 52 32.24 w150 52 19.07 w150 52 05.91 w150 51 52.74 w150 51 39,58 w150 51 26.42 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Total Dogleg for wellpath is 134.02 degrees. Vertical section is from 8 0.00 EO. 00 on azimuth 151.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64.34 64,34 64.83 65.94 66.96 69.64 72.80 93,67 99.06 103,25 112.50 121. 40 75.20 127.37 90.93 90.93 90.93 90,93 90,93 2772.92 2989.41 3205.91 3422.40 3638.89 90.93 90.93 90.93 90.93 90.93 3776.00 3855.39 4026,00 4071.88 4288.38 90.93 90.93 90.93 90.93 90.93 4504.87 4721.37 4937.86 5154.35 5370.85 90.93 90.93 90.93 90.93 90.93 5587,34 5803,84 5896,00 6020.33 6156.00 90.93 90.93 90,93 90.93 90.93 6236.82 6386.00 6453.32 6598,00 6657.69 6669.71 6693.00 6710.63 6747.67 6779,92 6799.00 295.805 303.118 306.228 310.428 315.008 317.735 322.778 325.048 329.938 331. 945 332.968 338.605 346.428 374.978 417.885 455.428 8909.30E 9359,94E 9551. 78E 9810.58E 10092.98E 10261. 22E 10571.73E 10711.86E 11013.02E 11137.27E 11162.53E 11213.00E 11252.66E 11340.93E 11425.18E 11479.99E 385916.14 385926.30 385930.58 385932.90 385949.64 385951. 34 385972.02 386001.12 386036.81 386068.04 386078.91 386127.22 386181.51 386241.51 386306.92 386377.43 386452.70 386489,96 386532.36 386616.02 386703.27 386737.44 387153.48 387603,92 387723.68 388054.35 388179.33 388191. 82 388504.79 388940.83 388955.22 389405.66 389856.09 390306.52 390756.96 391042.22 391207.39 391562.36 391657.83 392108.26 392558.70 393009.13 393459.56 393910.00 394360,43 PROP05AL LI5TING Page 2 Your ref CDl-14 Version#2 Last revised: 12-Feb-2001 G RID COO R D 5 Easting Northing 394810.87 395261.30 395453,06 395711.74 395994.01 396162.17 396472.54 396612,60 396913.63 397037.82 397063.06 397113.43 397152,96 397240.78 397324,34 397378.55 5975378.72 5975364.41 5975358.31 5975350.09 5975341.12 5975335.78 5975325.91 5975321. 46 5975311.89 5975307.95 5975306.54 5975300.11 5975291.67 5975261. 76 5975217,55 5975179.17 G E 0 G RAP H I C COO R DIN ATE 8 n70 20 31.01 n70 20 30.93 n70 20 30.90 n70 20 30.86 n70 20 30.81 n70 20 30,78 n70 20 30,72 n70 20 30.70 n70 20 30.64 n70 20 30.62 n70 20 30.61 n70 20 30.55 n70 20 30.48 n70 20 30.19 n70 20 29,77 n70 20 29.40 w150 51 13,25 w150 51 00.09 w150 50 54.48 w150 50 46.92 w150 50 38.67 w150 50 33.76 w150 50 24,69 w150 50 20.60 w150 50 11.80 w150 50 08.17 w150 50 07.43 w150 50 05,96 w150 50 04.80 w150 50 02.22 w150 49 59.76 w150 49 58,16 ') ) 13900.00 76.33 129,99 6806.59 474.118 11503.33E 397401. 60 5975160.12 n70 20 29.22 w150 49 57.48 13977.57 79.27 136.47 6823.00 526.028 11558.51E 397455.96 5975107.36 n70 20 28.71 w150 49 55.87 14000.00 80.14 138.32 6827.01 542.268 11573.45E 397470.64 5975090.88 n70 20 28.55 w150 49 55.44 14100.00 84.16 146.45 6840,68 620.688 11633.82E 397529.78 5975011.55 n70 20 27.77 w150 49 53.68 14168.91 87.00 151.98 6846.00 679,688 11668.96E 397563.99 5974952.02 n70 20 27.19 w150 49 52.66 14168.93 87.00 151. 99 6846.00 679,698 11668.97E 397564.00 5974952.00 n70 20 27.19 w150 49 52.66 14268.93 88.00 151.99 6850.36 767.898 11715.89E 397609.54 5974863.09 n70 20 26,32 w150 49 51.29 14368.93 89.00 151. 99 6852,98 856.148 11762.84E 397655.11 5974774.13 n70 20 25,45 w150 49 49.92 14449.43 89.81 151. 99 6853.82 927.218 11800.65E 397691.81 5974702.49 n70 20 24.76 w150 49 48.82 14500.00 89.81 151. 99 6853.99 971.858 11824.40E 397714.86 5974657.48 n70 20 24.32 w150 49 48.13 14600.00 89.81 151.99 6854.33 1060.138 11871.37E 397760.45 5974568.49 n70 20 23,45 w150 49 46.76 14700.00 89.81 151. 99 6854.67 1148.428 11918.34E 397806.03 5974479.49 n70 20 22.58 w150 49 45.40 14800.00 89.81 151. 99 6855.00 1236.708 11965.31E 397851. 62 5974390.50 n70 20 21. 71 w150 49 44.03 14900.00 89.81 151. 99 6855.34 1324.988 12012.28E 397897.21 5974301. 51 n70 20 20.84 w150 49 42.66 15000.00 89.81 151. 99 6855.67 1413.268 12059.25E 397942.80 5974212,51 n70 20 19.97 w150 49 41.30 15097.56 89.81 151. 98 6856.00 1499.398 12105.07E 397987.27 5974125.69 n70 20 19.12 w150 49 39.96 15100.00 89.81 151. 98 6856.01 1501.558 12106.22E 397988.38 5974123.52 n70 20 19.10 w150 49 39,93 15200.00 89.81 151. 98 6856.34 1589.838 12153.19E 398033.97 5974034,52 n70 20 18.23 w150 49 38.56 15300.00 89.81 151.98 6856.68 1678 .118 12200.16E 398079.56 5973945.53 n70 20 17.36 w150 49 37.20 15400.00 89,81 151. 98 6857.02 1766.398 12247.12E 398125.14 5973856.53 n70 20 16.49 w150 49 35.83 15500.00 89.81 151. 98 6857.35 1854.678 12294.09E 398170.73 5973767.54 n70 20 15.62 w150 49 34.46 15600.00 89.81 151. 98 6857.69 1942.968 12341.06E 398216.32 5973678.54 n70 20 14.76 w150 49 33.10 15700.00 89.81 151. 98 6858.03 2031.248 12388.03E 398261.91 5973589.55 n70 20 13,89 w150 49 31.73 15800,00 89.81 151. 98 6858.36 2119.528 12435.00E 398307.49 5973500.56 n70 20 13.02 w150 49 30.36 15900.00 89,81 151. 98 6858.70 2207.808 12481. 97E 398353.08 5973411. 56 n70 20 12.15 w150 49 29.00 16000.00 89.81 151. 98 6859.04 2296.098 12528.94E 398398.67 5973322.57 n70 20 11.28 w150 49 27.63 16100.00 89.81 151. 98 6859.37 2384.378 12575.91E 398444.25 5973233.57 n70 20 10,41 w150 49 26.26 16200.00 89.81 151. 98 6859.71 2472.658 12622.88E 398489.84 5973144.58 n70 20 09.54 w150 49 24.90 16300.00 89.81 151. 98 6860.05 2560.938 12669.85E 398535.43 5973055.58 n70 20 08.67 w150 49 23,53 16400.00 89.81 151. 98 6860.38 2649.228 12716.82E 398581.01 5972966.59 n70 20 07,80 w150 49 22.16 16500.00 89,81 151. 98 6860.72 2737.508 12763.79E 398626.60 5972877.59 n70 20 06.93 w150 49 20.80 16600.00 89.81 151. 98 6861.06 2825.788 12810.76E 398672.19 5972788.60 n70 20 06.06 w150 49 19.43 16700.00 89.81 151. 98 6861.39 2914.068 12857.73E 398717.78 5972699.61 n70 20 05.19 w150 49 18,06 16800.00 89.81 151. 98 6861.73 3002.348 12904.70E 398763.36 5972610.61 n70 20 04.32 w150 49 16.70 All data· in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Total Dogleg for wellpath is 134.02 degrees. Vertical section is from 8 0.00 E 0,00 on azimuth 151.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. PROP08AL LI8TING Page 3 CD#l,14 Your ref CDl-14 Version#2 Alpine Fie1d,North 81ope, Alaska Last revised : 12-Feb-2001 Measured Inc1in Azimuth True Vert R E C TAN GULAR G RID COO R D 8 G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 RDINATE8 Easting Northing C 0 0 R DIN A T E 8 16900.00 89.81 151. 98 6862.07 3090.638 12951. 67E 398808.95 5972521. 62 n70 20 03.46 w150 49 15,33 17000.00 89,81 151. 98 6862,40 3178.918 12998.63E 398854.54 5972432.62 n70 20 02.59 w150 49 13,97 17100.00 89.81 151.98 6862.74 3267.198 13 045. 60E 398900,12 5972343.63 n70 20 01. 72 w150 49 12.60 17200.00 89.81 151. 98 6863,07 3355.478 13092.57E 398945.71 5972254.63 n70 20 00,85 w150 49 11.23 17300.00 89.81 151. 98 6863.41 3443.768 13139.54E 398991. 30 5972165.64 n70 19 59.98 w150 49 09.87 17400.00 89.81 151. 98 6863.75 3532.048 13186.51E 399036.88 5972076.64 n70 19 59.11 w150 49 08,50 17500.00 89.81 151.98 6864.08 3620.328 13233.48E 399082.47 5971987.65 n70 19 58.24 w150 49 07.13 17600.00 89.81 151. 98 6864.42 3708.608 13280.45E 399128.06 5971898.65 n70 19 57.37 w150 49 05.77 17700.00 89.81 151. 98 6864.76 3796,898 13327.42E 399173.65 5971809.66 n70 19 56.50 w150 49 04.40 17800.00 89.81 151. 98 6865.09 3885.178 13374,39E 399219.23 5971720.67 n70 19 55,63 w150 49 03.04 17900.00 89,81 151. 98 6865.43 3973.458 13421. 36E 399264.82 5971631.67 n70 19 54.76 w150 49 01.67 18000.00 89.81 151. 98 6865.77 4061. 738 13468.33E 399310.41 5971542,68 n70 19 53.89 w150 49 00.30 18069.28 89.81 151. 98 6866.00 4122.898 13500.87E 399341,99 5971481. 02 n70 19 53.29 w150 48 59.36 18069.30 89.81 151. 98 6866.00 4122.928 13500.88E 399342.00 5971481. 00 n70 19 53,29 w150 48 59.36 18098.34 89.52 151. 99 6866.17 4148.558 13514.52E 399355.24 5971455.16 n70 19 53.04 w150 48 58.96 18500.00 89.52 151. 99 6869.54 4503.148 13703.15E 399538.31 5971097,70 n70 19 49.55 w150 48 53,48 19000.00 89.52 151. 99 6873.74 4944.568 13937.96E 399766,22 5970652.73 n70 19 45.20 w150 48 46,65 19269.36 89.52 151. 99 6876.00 5182.358 14064.46E 399888.99 5970413.02 n70 19 42.86 w150 48 42.97 19269.38 89,52 151. 99 6876.00 5182.378 14064,47E 399889.00 5970413.00 n70 19 42,86 w150 48 42.97 ) ) All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Total Dogleg for wellpath is 134.02 degrees. Vertical section is from 5 0.00 E 0,00 on azimuth 151.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#1,14 Alpine Field, North 51ope, Alaska PROP05AL LI5TING Page 4 Your ref CDl-14 Version#2 Last revised : 12-Feb-2001 Comments in wellpath ------ --- -- ------ --- ------ -------- --- --- MD TVD Rectangular Coords, Comment ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.005 O.OOE KOP 583.33 581. 64 17.865 22 . 86E Begin 4Deg Bld 708.78 704.08 35.025 43.90E Begin Fnl Trn 1075,57 1046.00 90.415 161.48E West 5ak 1747.43 1556.00 154.765 584.49E Permafrost 2038.18 1706.98 164.775 832.18E EOC 3132.94 2181. 00 180.775 1818.87E C40 3638.73 2400.00 188.175 2274.72E 9 5/8 " Casing pt 3652.59 2406.00 188.378 2287.21E C30 4484.02 2766.00 200.535 3036.57E C20 6816.65 3776.00 234.635 5138.92E K-3 7394.03 4026.00 243.085 5659.31E K-2 11712.86 5896.00 306.225 9551. ?BE Albian-97 12313.34 6156.00 315.005 10092.98E Albian-96 12844.53 6386.00 322.775 10571.73E HRZ 13334.15 6598.00 329.935 11013.02E K_1 13472.01 6657.69 331.945 11137,27E Begin Fn1 B1d/Trn 13555.89 6693.00 338,605 11213,00E LCU 13869.15 6799.00 455.425 11479.99E Miluveach A 13977.57 6823.00 526,025 11558.51E Alpine D 14168.91 6846.00 679.685 11668.96E Tgt/7 "Csgpt 14168.93 6846.00 679.695 11668.97E CDl-14 TgtCstPt Rvsd 8-Jan-01 14449.43 6853.82 927.218 11800.65E Fnl EOB 15097.56 6856.00 1499.395 12105.07E Base Alpine 18069.28 6866.00 4122.895 13500.87E Tgt I IntrmdPt 18069.30 6866.00 4122.925 13500.88E CDl-14 TgtIntrmdPt 8-Feb-01 18098.34 6866.17 4148.555 13514.52E End Angle Drop 19269,36 6876.00 5182.355 14064.46E TD 19269.38 6876.00 5182,378 14064.47E CDl-14 TgtTD Rvsd 8-Feb-Ol Casing positions in string 'A' -- -- -- - --- -- - - --- - -- --- - - ----- - - - - - ------- --- -- --- --- - --- --- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - -- - - - - -- - --- - - - -- --- - - - - - - - - - - - - - - - - -- - - - - - - --- - - - - - - - - -- -- - - - - - - - - - - - - - - --- 0.00 0.00 0.008 O.OOE 3638.73 2400.00 188.178 2274.72E 9 5/8" Targets associated with this wellpath -- --- - -- -- - ----- - - - --- ---- -- ------ --- -- --- - ---- - - ------ - -- - -- ---- --- --- --- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- CDl-14 TgtCstpt Rvsd 397564.000,5974952.000,0.0000 CDl-14 TgtIntrmdPt 8 399342.000,5971481.000,2.0000 CD1-14 TgtTD Rvsd 8 399889.000,5970413.000,0.0000 6846.00 6866.00 6876.00 679.698 4122.928 5182.378 11668.97E 13500.88E 14064.47E 17-Jan-2001 17-Jan-2001 8-Feb-2001 ) ) Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T ~ Baker Hughes INTEQ Your ref Our ref License CDl-14 Version#2 prop4423 Date printed Date created Last revised 12-Feb-2001 17-Jan-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath PMSS <0-10548'>, ,19,CD#1 PMSS <2827 - l1956'>,,19A,CD#1 PMSS IFR <564-18590'>,,17,CD#1 PMSS <10803-13706'>,,24,CD#1 PMSS <0-9357'>,,16PH1,CD#1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <7182 - 11170'>,,41,CD#1 PMSS <475 - 8166'>,,41PH1,CD#1 PMSS <9081 - 12811'>, ,44,CD#1 PMSS <297 - 9882'>, ,44PH1,CD#1 PMSS <476 - 11190'>, ,34,CD#1 PMSS <0-10897'>, ,3,CD#1 PMSS <0-8350'>, ,26PH1,CD#1 PMSS <7755-11134'>,,26,CD#1 PMSS <0-8844'>, ,45PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <0-10504'>,,5PH1,CD#1 PMSS <9499 - 14515'>, ,5,CD#1 PMSS <0-12921'>, ,43,CD#1 PMSS <832 - 12147'>,,25,CD#1 PMSS <384 - 14477'>,,23,CD#1 PGMS <0-10255'>"WD2,CD#1 PMSS <0-7331'>, ,lPH1,CD#1 PMSS <5946 - 10289'>, ,1,CD#1 PMSS <563-13977'>, ,4,CD#1 PMSS <0-11492'>,,27,CD#1 PMSS <565 - 9505'>, ,30PH1,CD#1 PMSS <8965 - 12850'>, ,30,CD#1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 6-Apr-2000 49.7 100.0 100.0 30-Apr-2000 49.7 100.0 100.0 20-0ct-2000 29.2 350.0 18260.0 7-Aug-2000 99.9 0.0 15700,0 4-Jan-2000 17.2 ~?8,9 538,9 25-0ct-1999 17.2 538.9 14500.0 3-Apr-2000 269.6 100.0 100.0 26-Mar-2000 269.6 100.0 100.0 23-May-2000 300.0 100.0 14202.3 23-May-2000 300.0 100.0 14202.3 11-May-2000 199.8 200.0 200.0 4-Jan-2000 109.9 294.4 294.4 6-Mar-2000 120.1 100.0 100.0 1-Nov-1999 120.1 100.0 14900.0 4-Jan-2000 309.8 200.0 200.0 16-Nov-1999 309,8 200.0 200.0 23-Dec-1999 279.9 100.0 14268.9 23-Jan-2000 88.9 327.8 327.8 23-Jan-2000 88.9 327.8 10660.0 27-0ct-2000 290.2 100.0 14401.1 15-Mar-2000 109.5 294.4 15700.0 29-Aug-2000 74.4 860.0 15600.0 28-Jun-1999 1014.9 1550.0 1550.0 29-Feb-2000 129.7 250.0 250.0 27-Jun-1999 129.7 250.0 19140.0 15-Nov-2000 100.1 100.0 9380.0 16-Mar-2000 129.8 200,0 15300,0 25-Sep-2000 159.9 100.0 18920.0 1-0ct-2000 159.9 100.0 18920.0 ) PMSS <473 - 14364'>, ,31,CD#1 PMSS <10013' - 14353'>,,32,CD#1 PMSS <0-11067'>, ,32PH1,CD#1 PMSS <0-11693'>, ,10,CD#1 PMSS <562 - 12134'>, ,37,CD#1 PMSS <654 - 10956'>, ,38PB1,CD#1 PMSS <9876 - 12240'>, ,38,CD#1 PMSS <0-10224'>, ,39PH1,CD#1 PMSS <9146 - 13289'>, ,39,CD#1 PMSS <0-12055'>, ,40,CD#1 PMSS <10879 - 11934'>, ,9PH,CD#1 PMSS IFR <0 - 15350'>, ,9,CD#1 PMSS <656 - 7210'>, ,28PH1,CD#1 PMSS <6549 - 10468'>, ,28,CD#1 PMSS <507 - 10854'>, ,33,CD#1 PGMS <0 - 8050'>, ,22,CD#1 PMSS <8091 - 8372'>,,22,CD#1 PMSS <8464 - 11500'>,,22A,CD#1 PMSS <472 - 1545'>, ,36PH1,CD#1 PMSS <763 - 7440'>,,36PH2,CD#1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <0-13450'>, ,35,CD#1 PMSS <0-12773'>,,2,CD#1 PMSS <0-12741'>"NQ1PH,CD#1 PMSS <10161 - 16118'>,,29,CD#1 PMSS w/IFR <12632-13308'>,,6PH,CD#1 PMSS w/IFR <0-16024'>,,6,CD#1 PMSS <0-11300'>,,13,CD#1 PMSS <385-8950'>, ,21PH1,CD#1 PMSS <8460 - ???'>,,21,CD#1 27-0ct-2000 14-Dec-2000 4-Jan-2000 8-Dec-2000 26-Aug-1999 13-Feb-2000 14-Feb-2000 4-Jan-2000 22-Sep-1999 5-Sep-2000 18-0ct-2000 18-0ct-2000 17-Dec-2000 22-Dec-2000 5-Jan-2001 13-Nov-2000 13-Nov-2000 13-Nov-2000 4-Jan-2000 4-Jan-2000 22-Dec-1999 24-Jul-2000 24-Jan-2001 19-Jan-2001 31-Jan-2001 8-Feb-2001 8-Feb-2001 27-Sep-2000 12-Feb-2001 12-Feb-2001 168,2 179.7 179.7 39.0 229.9 239.5 239.5 249.8 249.8 259.9 37.5 37.5 137.2 137.2 189,9 80.1 80.1 80.1 220.0 220.0 220.0 209.7 120.1 149.7 149.7 80.3 80.3 9.9 6"9··.·6 69.6 583.3 294.4 294,4 405.6 0.0 200.0 200.0 100.0 100.0 100.0 790.9 790.9 372.2 372.2 0.0 100.0 100,0 100.0 100.0 100.0 100.0 100.0 200.0 100.0 100.0 338.9 338.9 100.0 272.2 272.2 ) 583.3 294.4 294.4 6600.0 15900.0 200.0 200.0 100.0 100,0 100.0 790.9 11840.0 372.2 372.2 272,2 13600.0 13600.0 13600.0 100.0 100.0 100.0 100.0 12340.0 100.0 19240.0 338.9 13506.2 8040,0 19240.0 19240.0 ') ') Phillips Alaska, Inc. CD#l 14 slot #14 Alpine Field North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref Our ref License CDl-14 Version#2 prop4423 Date printed Date created Last revised 12-Feb-2001 17-Jan-2001 12-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.004,w150 55 33.514 Slot Grid coordinates are N 5975812.993, E 385908.001 Slot local coordinates are 314.39 S 2482.62 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#l,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 128.00 100.00 0.00 S 0.00 E 0.00 0.48 0.48 0.26 N/A 200.00 0.00 128.00 200.00 0.00 S 0.00 E 0.00 0.96 0.96 0.52 N/A 250.00 0.00 128.00 250.00 0.00 S 0.00 E 0.00 1.19 1.19 0.65 N/A 350.00 3.00 128.00 349.95 1. 61 S 2.06 E 2.39 1. 90 1. 67 0.90 38.00 450,00 6.00 128.00 449.63 6.44 S 8.24 E 9.56 2.80 2.16 1.17 38.00 550.00 9.00 128.00 548.77 14.48 S 18.53 E 21. 48 3.76 2.65 1. 45 38.00 583.33 10.00 128.00 581. 64 17.86 S 22.86 E 26.51 4.08 2.82 1. 55 38.00 600.00 10.66 128.37 598.04 19.71 S 25.21 E 29.24 4.24 2.90 1. 60 38.02 700.00 14.65 129.90 695.59 33.57 S 42.17 E 49.45 5.21 3.44 1. 92 38,41 708.78 15.00 130,00 704.08 35.02 S 43.90 E 51. 53 5.29 3.48 1. 95 38.44 800.00 17.76 121. 48 791.60 49.87 S 64.81 E 74.47 6.17 4.00 2.28 37,39 900.00 21. 08 114.77 885.91 65.38 S 94.15 E 101. 94 7.11 4.63 2.68 35.77 1000.00 24.60 109.87 978.06 79.99 S 130.08 E 131.71 8.02 5.34 3.12 34.28 1075.57 27.35 106.96 1046.00 90.41 S 161.48 E 155.65 8.70 5.97 3.49 33.53 1100.00 28.24 106.14 1067.61 93.65 S 172.40 E 163.64 8.91 6.18 3.61 33.28 1200.00 31. 96 103.21 1154.11 106.28 S 220.92 E 197.58 9.79 7.16 4.16 33.23 1300.00 35.74 100.83 1237.14 11 7.82 S 275.40 E 233.35 10,65 8,35 4.75 35.05 1400.00 39.55 98.86 1316.31 128.21 S 335.57 E 270.78 11.56 9.73 5.40 41. 44 1500.00 43.40 97.18 1391. 22 137.41 S 401.14 E 309.70 12.70 11.18 6.11 58.80 1600.00 47.26 95.72 1461. 51 145.37 S 471.79 E 349.90 14.55 12.30 6.86 79.59 1700.00 51.14 94.44 1526.84 152.04 S 547.18 E 391.20 17.16 13.11 7.66 88.73 1747.43 52.99 93.88 1556.00 154.76 S 584.49 E 411.12 18.72 13,43 8.06 90.30 1800.00 55.03 93.29 1586.89 157.41 S 626.94 E 433.40 20.45 13.78 8.50 92.05 1900.00 58.94 92.24 1641.37 161. 44 S 710.68 E 476.28 24.51 14.38 9.38 93.22 2000.00 62.85 91. 28 1690.00 164.11 S 797.99 E 519.64 29.47 14,92 10.30 93.47 2038.18 64.34 90.93 1706.98 164.77 S 832.18 E 536.28 31.54 15.11 10.66 93.45 2500.00 64.34 90.93 1906.94 171.52 S 1248.41 E 737.71 57.17 17.50 15.00 92.76 3000.00 64.34 90.93 2123.44 178.83 S 1699.05 E 955.80 85,38 20,09 19.67 92.27 3132.94 64.34 90.93 2181. 00 180.77 S 1818.87 E 1013.79 92.92 20.78 20.90 92.19 3500,00 64.34 90.93 2339.93 186.14 S 2149.69 E 1173.89 113.73 22.67 24.32 91. 98 3638.73 64.34 90.93 2400.00 188.17 S 2274.72 E 1234.40 121. 61 23.38 25.61 91.93 3652.59 64.34 90.93 2406.00 188.37 S 2287.21 E 1240.44 122,40 23,45 25.74 91.92 4000.00 64,34 90.93 2556.42 193.45 S 2600.33 E 1391. 97 142.14 25.23 28.96 91. 79 4484.02 64.34 90.93 2766.00 200.53 S 3036.57 E 1603.09 169.66 27.70 33.45 91. 66 4500.00 64.34 90.93 2772.92 200.76 S 3050.97 E 1610.06 170.57 27.78 33.60 91. 66 5000.00 64.34 90.93 2989.41 208.07 S 3501.61 E 1828.15 199.02 30.32 38.24 91. 56 5500.00 64.34 90.93 3205.91 215.38 S 3952.25 E 2046.23 227.48 32.86 42.87 91. 49 6000.00 64.34 90.93 3422.40 222.69 S 4402,89 E 2264.32 255.94 35.39 47.51 91.43 6500.00 64,34 90.93 3638.89 230.00 S 4853.53 E 2482.40 284.41 37.91 52.14 91. 38 6816.65 64.34 90.93 3776.00 234.63 S 5138.92 E 2620.52 302.45 39.51 55.07 91. 35 7000.00 64,34 90.93 3855,39 237.31 S 5304.17 E 2700.49 312.89 40.44 56.77 91. 34 7394.03 64.34 90.93 4026.00 243.08 S 5659.31 E 2872.36 335.33 42.42 60.42 91. 31 7500.00 64.34 90.93 4071.88 244.63 S 5754.81 E 2918.58 341,36 42.95 61. 40 91. 31 8000.00 64.34 90.93 4288.38 251.94 S 6205.45 E 3136,66 369.84 45,47 66.03 91. 28 8500,00 64,34 90.93 4504.87 259.25 S 6656.09 E 3354.75 398.32 47.98 70.66 91. 26 9000.00 64.34 90,93 4721,37 266.56 S 7106.73 E 3572.84 426.80 50.50 75.30 91. 23 9500.00 64.34 90.93 4937.86 273.87 S 7557.37 E 3790.92 455.29 53.01 79.93 91.22 10000.00 64.34 90.93 5154.35 281.18 S 8008.01 E 4009.01 483.77 55.52 84.55 91. 20 10500.00 64.34 90.93 5370.85 288,49 S 8458,66 E 4227.10 512.25 58.02 89.18 91.18 All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead, Vertical section is from S 0.00 E 0.00 on azimuth 151.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ") Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#1,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN ATE S Sect Major Minor Vert. Azi. 11000.00 64.34 90.93 5587.34 295.80 S 8909.30 E 4445.18 540,74 60.53 93.81 91.17 11500.00 64.34 90.93 5803.84 303,11 S 9359.94 E 4663.27 569.22 63.04 98.44 91.16 11712.86 64.34 90.93 5896.00 306.22 S 9551. 78 E 4756.11 581.35 64.10 100.41 91.16 12000.00 64.34 90.93 6020.33 310.42 S 9810.58 E 4881.36 597.71 65.54 103.07 91.15 12313.34 64.34 90.93 6156.00 315.00 S 10092.98 E 5018.03 615.56 67.11 105.97 91. 14 12500.00 64.34 90.93 6236.82 317.73 S 10261.22 E 5099.44 626.20 68.04 107.70 91.14 12844.53 64.34 90.93 6386.00 322.77 S 10571.73 E 5249.72 645.83 69.77 110.89 91.13 13000.00 64.34 90.93 6453.32 325.04 S 10711.86 E 5317.53 654.68 70.55 112.33 91.13 13334.15 64.34 90.93 6598.00 329.93 S 11013.02 E 5463.28 673.72 72.22 115.43 91.12 13472.01 64.34 90,93 6657.69 331.94 S 11137.27 E 5523.41 681.57 72.91 116.70 91.12 13500.00 64,83 93.67 6669.71 332.96 S 11162.53 E 5536.17 683.23 73.05 116.96 91.13 13555.89 65,94 99.06 6693.00 338.60 S 11213.00 E 5564.85 686.74 73.31 117.49 91.19 13600.00 66.96 103.25 6710.63 346.42 S 11252.66 E 5590.38 689,52 73.52 117.90 91. 24 13700.00 69.64 112.50 6747.67 374,97 S 11340.93 E 5657.04 695,34 73.95 118.86 91. 43 13800.00 72.80 121. 40 6779.92 417.88 S 11425.18 E 5734.49 700.09 74.35 119.84 91. 65 13869.15 75.20 127.37 6799.00 455.42 S 11479.99 E 5793.37 702.58 74.61 120.53 91. 81 13900.00 76.33 129.99 6806.59 474.11 S 11503.33 E 5820.83 703.69 74.72 120.83 91. 88 13977.57 79.27 136.47 6823.00 526.02 S 11558.51 E 5892.58 705.67 74.98 121. 62 92.05 14000.00 80.14 138.32 6827.01 542.26 S 11573.45 E 5913.94 706.24 75.06 121. 84 92.10 14100.00 84,16 146.45 6840,68 620.68 S 11633.82 E 6011.51 707.95 75.38 122.87 92.29 14168.91 87.00 151. 98 6846.00 679.68 S 11668.96 E 6080.10 708.79 75.61 123.58 92.41 14168.93 87.00 151.99 6846.00 679,69 S 11668.97 E 6080,12 708.79 75.61 123.58 92.41 14268.93 88.00 151. 99 6850.36 767.89 S 11715.89 E 6180.03 710.03 75.95 124.62 92.57 14368.93 89.00 151.99 6852.98 856.14 S 11762.84 E 6279.99 711.26 76.29 125.66 92.74 14449.43 89.81 151. 99 6853.82 927.21 S 11800.65 E 6360.48 712.26 76.57 126.49 92.87 14500.00 89.81 151. 99 6853.99 971.85 S 11824.40 E 6411.06 712.89 76.74 127.02 92.95 14600.00 89.81 151.99 6854.33 1060.13 S 11871.37 E 6511.05 714.14 77.08 128.06 93.12 14700.00 89.81 151.99 6854.67 1148.42 S 11918.34 E 6611.05 715.40 77.43 129.10 93.28 14800.00 89.81 151. 99 6855.00 1236.70 S 11965,31 E 6711.05 716.66 77.79 130.14 93.45 14900.00 89.81 151. 99 6855.34 1324.98 S 12012.28 E 6811.05 717.93 78.14 131.18 93.61 15000.00 89.81 151. 99 6855,67 1413.26 S 12059.25 E 6911.05 719.21 78.50 132.21 93.77 15097,56 89.81 151. 98 6856.00 1499.39 S 12105.07 E 7008.62 720.46 78.86 133.23 93.93 15100.00 89.81 151.98 6856.01 1501. 55 S 12106.22 E 7011.05 720.49 78.87 133.25 93.94 15200.00 89.81 151,98 6856.34 1589.83 S 12153.19 E 7111.05 721.77 79.23 134.29 94.10 15300.00 89.81 151.98 6856.68 1678.11 S 12200.16 E 7211.05 723.07 79.60 135.33 94.26 15400.00 89,81 151.98 6857.02 1766.39 S 12247.12 E 7311.05 724.36 79.98 136.37 94.42 15500.00 89.81 151.98 6857,35 1854.67 S 12294.09 E 7411.05 725.67 80.35 137.40 94,58 15600.00 89.81 151.98 6857.69 1942.96 S 12341.06 E 7511.05 726.98 80.73 138.44 94.74 15700.00 89.81 151. 98 6858.03 2031.24 S 12388.03 E 7611.05 728.29 81.12 139.48 94.90 15800.00 89.81 151.98 6858,36 2119.52 S 12435.00 E 7711.05 729.61 81.50 140.51 95.06 15900.00 89.81 151. 98 6858,70 2207.80 S 12481. 97 E 7811.05 730.94 81. 89 141. 55 95.21 16000.00 89.81 151. 98 6859.04 2296.09 S 12528.94 E 7911.05 732.27 82.28 142.59 95.37 16100,00 89.81 151. 98 6859.37 2384.37 S 12575.91 E 8011. 05 733.61 82.68 143.62 95.53 16200.00 89.81 151. 98 6859.71 2472.65 S 12622,88 E 8111,05 734.96 83.07 144.66 95.68 16300.00 89.81 151. 98 6860.05 2560.93 S 12669.85 E 8211.05 736.31 83.47 145.69 95.84 16400.00 89.81 151.98 6860.38 2649.22 S 12716,82 E 8311. 04 737.66 83.87 146.73 96.00 16500.00 89,81 151.98 6860.72 2737.50 S 12763,79 E 8411. 04 739.02 84.28 147.76 96.15 16600.00 89.81 151.98 6861.06 2825.78 S 12810.76 E 8511. 04 740.39 84.68 148.80 96.31 16700.00 89.81 151.98 6861,39 2914,06 S 12857.73 E 8611. 04 741.76 85.09 149.83 96.46 16800.00 89.81 151.98 6861,73 3002.34 S 12904.70 E 8711.04 743,14 85,50 150,86 96.61 All data is in feet unless otherwise stated, Coordinates from slot #14 and TVD from RKB (Doyon 19) (56.00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110,23 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 151.99 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 3 CD#1,14 Your ref CDl-14 Version#2 Alpine Field,North Slope, Alaska Last revised : 12-Feb-2001 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN A T E S Sect Major Minor Vert. Azi. 16900.00 89.81 151.98 6862.07 3090.63 S 12951.67 E 8811.04 744.52 85.91 151. 90 96.77 17000.00 89.81 151.98 6862.40 3178.91 S 12998.63 E 8911.04 745.91 86.33 152.93 96.92 17100.00 89,81 151.98 6862.74 3267.19 S 13045.60 E 9011. 04 747.30 86.74 153.97 97.07 17200.00 89.81 151. 98 6863.07 3355.47 S 13092.57 E 9111.04 748.70 87.16 155.00 97,22 17300.00 89.81 151.98 6863.41 3443.76 S 13139.54 E 9211. 04 750.10 87,58 156.03 97.37 17400.00 89.81 151.98 6863.75 3532.04 S 13186.51 E 9311.04 751.51 88.00 157.07 97.52 17500.00 89.81 151. 98 6864.08 3620.32 S 13233.48 E 9411.04 752.93 88.42 158.10 97.67 17600.00 89.81 151. 98 6864.42 3708.60 S 13280.45 E 9511.04 754.35 88.84 159.13 97.82 17700.00 89.81 151.98 6864.76 3796.89 S 13327.42 E 9611.04 755.77 89.27 160.16 97.97 17800.00 89.81 151. 98 6865.09 3885.17 S 13374.39 E 9711. 04 757.20 89.70 161.20 98.12 17900.00 89.81 151. 98 6865.43 3973.45 S 13421.36 E 9811.04 758.64 90.12 162.23 98.27 18000.00 89.81 151. 98 6865.77 4061.73 S 13468.33 E 9911.04 760.08 90.55 163.26 98.41 18069.28 89,81 151. 98 6866.00 4122.89 S 13500.87 E 9980.32 761.08 90.85 163.98 98.52 18069.30 89.81 151. 98 6866.00 4122.92 S 13500.88 E 9980.34 761. 08 90.85 163.98 98.52 18098.34 89.52 151. 99 6866.17 4148.55 S 13514.52 E 10009.38 761.50 90.98 164.28 98,56 18500.00 89.52 151. 99 6869.54 4503.14 S 13703.15 E 10411. 02 767.36 92.72 168.42 99.14 19000.00 89.52 151. 99 6873.74 4944.56 S 13937.96 E 10911.00 774.77 94.92 173.57 99.86 19269.36 89.52 151. 99 6876.00 5182,35 S 14064.46 E 11180.35 778.81 96.11 176.34 100.24 19269.38 89.52 151. 99 6876,00 5182.37 S 14064.47 E 11180,37 778.81 96.11 176,34 100.24 POSITION UNCERTAINTY SUMMARY ------------------------------ ------------------------------ Depth From To Survey Tool Error Model Position Uncertainty Major Minor Vert. ---------------------------------------------------------------------------------------------------- o 19269 MWD + IFR (Alaska) - Corrected Dat User specified 778.81 96.11 176.34 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #14 and TVD from RKB (Doyon 19) (56,00 Ft above mean sea level). Bottom hole distance is 14988.87 on azimuth 110.23 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 151.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) Phillips Alaska, Inc. CD#1,14 Alpine Field,North 81ope, Alaska MD TVD Rectangular Coords. ') PROP08AL LI8TING Page 4 Your ref CDl-14 Version#2 Last revised : 12-Feb-2001 Comments in wel1path -------------------- -------------------- Comment ----------------------------------------------------------------------------------------------------------- 250,00 583.33 708.78 1075.57 1747.43 2038.18 3132.94 3638.73 3652,59 4484.02 6816.65 7394.03 11712.86 12313.34 12844.53 13334.15 13472.01 13555.89 13869.15 13977.57 14168.91 14168.93 14449.43 15097.56 18069.28 18069.30 18098.34 19269.36 19269.38 250.00 581. 64 704.08 1046.00 1556.00 1706.98 2181. 00 2400.00 2406.00 2766.00 3776.00 4026.00 5896.00 6156.00 6386.00 6598.00 6657.69 6693.00 6799.00 6823.00 6846.00 6846.00 6853.82 6856.00 6866.00 6866.00 6866.17 6876.00 6876.00 Top MD Top TVD 0.00 8 17.86 8 35.02 8 90.41 8 154.76 8 164.77 8 180.77 8 188.17 8 188.37 8 200.53 5 234.63 5 243.08 8 306.22 8 315.00 8 322.77 5 329.93 5 331. 94 8 338.60 5 455.42 5 526.02 8 679.68 8 679.69 8 927.21 8 1499.39 8 4122.89 8 4122.92 8 4148.55 8 5182.35 8 5182.37 5 0.00 E 22.86 E 43.90 E 161. 48 E 584.49 E 832.18 E 1818.87 E 2274.72 E 2287.21 E 3036.57 E 5138.92 E 5659.31 E 9551.78 E 10092.98 E 10571.73 E 11013.02 E 11137.27 E 11213.00 E 11479.99 E 11558.51 E 11668.96 E 11668.97 E 11800.65 E 12105.07 E 13500.87 E 13500.88 E 13514,52 E 14064.46 E 14064.47 E 0.008 Rectangular Coords, O.OOE 3638.73 2400.00 188.175 Rectangular Coords. 2274.72E 9 5/8" KOP Begin 4Deg Bld Begin Fn1 Trn West 5ak Permafrost EOC C40 9 5/8" Casing pt C30 C20 K-3 K-2 Albian-97 Albian-96 HRZ K_1 Begin Fnl Bld/Trn LCU Miluveach A Alpine D Tgt/7 "Csgpt CDl-14 TgtCstPt Rvsd 8-Jan-01 Fnl EOB Base Alpine Tgt/ Intrmdpt CDl-14 TgtIntrmdPt 8-Feb-01 End Angle Drop TD CDl-14 TgtTD Rvsd 8-Feb-01 Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD Casing ----------------------------------------------------------------------------------------------------------- Target name 0.00 0.00 Geographic Location Targets associated with this wellpath T,V.D. Rectangular Coordinates Revised ------------------------------------- ------------------------------------- ----------------------------------------------------------------------------------------------------------- CDl-14 TgtCstPt Rvsd 397564.000,5974952.000,0.0000 CDl-14 TgtIntrmdPt 8 399342.000,5971481,000,2.0000 CDl-14 TgtTD Rvsd 8 399889.000,5970413.000,0.0000 6846.00 6866.00 6876.00 679.698 4122.928 5182.378 11668.97E 13500.88E 14064.47E 17-Jan-2001 17-Jan-2001 8-Feb-2001 RECEIVED FEB 1 3 2001 Alaska Oil & Gas Cons. Commission Anchorage ) ') Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 February 13, 2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska, 99501 Re: Application for Permit to Drill CD1-14 (& CD1-14 PH) RECEIVED FEB 13 2001 Dear Sirs: Alaska Oil & Gas Cons. lIommission 8ncl1oraae Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore gas injection well from the Alpine CD1 drilling pad. The intended spud date for this well is February 19, 2001. It is intended that Doyon Rig 19 be used to drill the well. The CD1-14 PH will be drilled through to the base of the Alpine Sand at an inclination of approximately 64.3°. This will allow evaluation of the reservoir interval. It will then be plugged back and sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 711 intermediate casing, a CBL log will be run on electric line, then the horizontal section will be drilled and the well completed as an open hole injector. At the end of the work program, it is planned to pre-produce the well for a period up to six months. Following the pre-production period, CD1-14 will be shut in until injection operations commence. As per AOGCC regulations 20 AAC 25.412 (b) it is requested that permission be given to place the production packer at +1-13,444' MD. This is +1- 660' MD from the top of the Alpine. This request is being made so that the hole inclination will be low enough to enable running slickline tools to the packer and X nipple depth. A similar request was made prior to drilling CD1-06, due to the geometry of the well. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed pilot hole schematic. 6. Proposed completion diagram. 7. Proposed completion diagram with open hole isolation options. 8. Pressure information as required by 20 ACC 25.035 (d)(2). 9. CD1-14 and CD1-14PH Cementing Requirements. 10. Directional drilling 1 collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as ) required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. ~) If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~'- ~ - ~. Vern JOhn6 - Drilling Engineer Attachments cc: CD1-14 Well File / Sharon Allsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin A TO 8680 A TO 868 ATO 810 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @ anadarko.com RECE\\JEQ FEB "\ 3 LOO' commission . Gas co~s. Naska 0\\ &. þ.~cno{age ) ." .) 200-083-CD10~pkr.txt Subject: CD1-06 (Proposed PTD 200-083) Date: Wed, 07 Jun 2000 16:10:34 -0800 From: Tom Maunder <tom maunder@admin.state.ak.us> To: Brian Robertson <brobert4@ppco.com> CC: Blair Wondzell <blair wondzell@admin.state.ak.us> Brian, Thanks for getting back to us with your proposal. We do understand th e rationale regarding the request to set the packer and associated jewel ry shallower than the regulations proscribe. We also appreciate your addressing the necessity of isolation and your proposal to determine that isolation is present above the proposed packer setting depth prio r to running the completion. Based on your message and our discussions I understand your plan to be as follows: ...pump sufficient cement to place the top of cement some 900' to 1000 , md above the top of the Alpine sand ...run a cement quality log (CQL) before running the completion to determine effective isolation ...after assessing the cement quality and TOC, propose a packer settin 9 depth consistent with the determined quality information Provided adequate isolation is evidenced by the CQL, you are free to propose setting the packer at a shallower depth than proscribed by the regulations. When the CQL is available, please contact us so we may view the log. Again, thanks for your efforts on this matter. Please contact myself or Blair with any questions. Tom Maunder Petroleum Engineer AOGCC Subject: CDI-06 Packer Setting Depth Date: Mon, 5 Jun 2000 15:25:11 -0900 From: "Brian Robertson" <BROBERT4@ppco.com> To: tom maunder@admin.state.ak.us Page 1 . ) ) . 200-083-CD106pkr.txt CC: "Douglas K Chester" <DCHESTER@ppco.com>, Blair wondzell@admin.state.ak.us Tom, Further to our conversation this morning, there follows somé thoughts / proposals regarding the packer setting depth on the CD1-06 well. Doug and I would be happy to come over and discuss this with you and Blair - at your convenience. Please let me know a suitable time. Brian....... Attached is the blown up schematic for the proposed CDI-06 gas injecti on well completion. This plan recommends setting the packer at +/- 12500' MD. This is some 716' above the top of Alpine. An exception from the standard 200' MD maximum distance between the packer setting depth and Top Alpine has been requested in the APD. To compensate for this 'high , packer setting depth, it is intended the top of cement be raised to so me 916' MD above the Alpine (as opposed to the standard 500' MD). This will allow for cement isolation some 200' MD above the packer. This will also provide addition back up to t he increased amount of casing exposed to injection fluids underneath the packer. The rationale behind choosing this packer setting depth was as follows: 1. Wellbore geometry: to maintain the completion within 'wirelineable limits the XN nipple needs to be at a maximum inclination of around 67 deg. We have had some success at getting wireline and USIT logs to around 70+ deg. However this has been in lower step out wells. 2. The setting depth shown below, also allows for some 240' MD from th e end of tubing to 68 deg inclination at 12800' MD. This is the distance ove r which a SCMT (cement evaluation log) could realistically be run post-completio n. Note, if the cement evaluation log was run pre-completion this distanc e Page 2 ) . ) . 20Q-083-CD106pkr.txt would not all be required and the packer could be set +/- 200' deeper. 3. Setting the packer within 200' of the top Alpine is undesirable fro m a future completion perspective. Future well work operations would have to be conducted using coiled tubing as opposed to slickline. (Embedded image moved to file: pic26527.pcx) Proposal: Running the US IT log on electric line, pre-completion should allow the cement quality to be determined to a depth very close to the top of th e Alpine (78 deg inclination). Based on this information (and on the rea I wellbore surveys) we could then choose the optimal packer setting dept h for the well. Some guidance from the AOGCC will be necessary to determine if it is still permissible to run a 'wirelineable' completio n or if it will be necessary to set the packer within 200' of the Alpine ----~-----~------------------------------------------------------- Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder Petroleum Engineer .us> Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage AK 99501 USA Additional Last Name First Name Version <tom maunder@admin.state.ak Fax: 907 276-7542 Work: 907 793-1250 Conference Software Address Information: Maunder Tom 2.1 Page 3 Issued by Irttegrated Payment System, Ine. EnBIeWood'CoJørad.O . jXjN.OTYAlID FOR~.....M. O..U....NT VER$/OOO. t Payable at NolWest Bank of Grand Junction - DowntoWn. NA . SHA:RON UP~ Grand Junction, Colorado. / PERIOD ENDING (./ ~.h-'..' 7- I ¿:v I: .0 2 .001.,001::' 5 '" 0 ¡. ? 5000 5 ~ b"·O . . 2 . . ....-. DATE (e-Þv ,/,;¿'ý /3( 2øo / 02-10/'021 ~~~::6F.H.:.....tf.V$h..·.·".sfk p~ ¿ ~~ve I SI¡Co.eV .- (¡d- 'faµ;iyJ ;Li~ ~ /;ð&" DOLLARS 112 Cash Advance Draft American Express~ r (} /êtJ.. WELL PERMIT CHECKLIST COMPANY ~ / / II {5 WELL NAME eo ( -It{ PROGRAM: exp _ dev ~ redrll_ serv _ well bore seg _ann. disposal para req_ FIELD & POOL /ZO/ct) INITCLASS 'h..;=U ({)!L. * GEOLAREA ¿....7tõ UNIT# c>_Ç03(~() ON/OFF SHORE OJ/! ADMINISTRATION 1. Permitfeeattached.......... '11.)" ~h"'" ',' Cf-)N*¿Jellvi/(¿¿rrc;'I!n:x1.uad'¡¿"-~'¡'O~N~IIt~)~ 6£...~¡1v~Þð4S/;'jec.Þ~, 2. Le~se number appropriate.~~ ~...£~. f!CQ-t>I.~rr~"?'J: /O~Y'ð7~vy-~ k)c"'}nu-h.. ~ ~D.L 02-Ç~51) .~e., f'rt;JcluL'h~ lÞl k5 //4...( .Æ 3. Umquewell name and number... . . . . . . . . . . . . . , . N ~ APt 372.C>l}Ç') I· 'b. i.'I\.. 02-SS1d:;JÞ ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N, 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N APPR DATE 12. Permit can,be issued without administrative approval.. . . . . N ~ Z ,1"· 0 i 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . @ N 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N ,~ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y.. ~ ~~\o.~7\"Ð~ \ ...:)\~\ ~ö...~ ~ ,,'0.. ~~ç:) 18. CMT will cover all known pro. ductive horizons. . . . . . . . . . ª OVt-, t""'-.. ~\I;"(. c€'~""''(> '<l.~~ ~ ~~)$""I~rl 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 'N Q:.:f..\~'~~ "'-~ i ~ ~~~, ~'\~ ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . '¥-f+ '" ~ '~~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N <:"\o~ QÇ~~<2 '" \¿)<e~~,\(ê-,-1.. "t\'~\"""'~y\'r\ ,-,\~ r 23. If diverter required, does it meet regulations. . . , . . . . . . N - 24. Drilling ,fluid program schematic & equip list adequate. . .' . . N 25. 80PEs, do they meet regulation. . . . . . . . .~~. . . . N \. ~ . ~. DATE ,26. BOPE press rating appropriate; test to ?;)ö-J\....J psig. N ~~<>'V ~c::.~\~~ J"'ö '?"'7' ~~" l ;Jfr ç- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . y ® 30. Permit can be issued w/o hydrogen sulfide measures. . . .. Y'/:!y ' ., . . 31. Da~a ~resented. on potential overpressure zones . . . . , . . ól.f3 ,/lIr'K..t... ¡C"ð/-nt.:¡ h.Q-,. ~ k-llbnéTl"u 4(& ¡:;~s f..}x-J e/ue -Jb.&4.:5 /~/;-¡;:-h¿"?1-, 32. Selsmlcanal~~lsofshallo~gaszones. . . . . . . . . . . . '. 2/'IQ tA<--.I1..~.~-'1. ~f.C¡;)I.O", 46· /þt-:.¡7ð-t'-hÞ1<- /J'tL4Sv,.L.;S "¿><..VÞ<&f ~ APPR DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . fiA Y N ~ ~ ~ r~¡'~~""""'" ,/5l> /0) 2.' ¡t{, 0 ( 34. Contact name/phone for weekly progress reports [explora(ptý only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ#ç ~~W WM 8~s CifÍ / ¡(.~ ~. rtyC~~ , .~ TEM IfhM. ''1\ c;) JMH d1vn~ Z-() $./01 GEOLOGY APPR DATE t.~;"¡ý'/~ ¡4~Y""41 AI ill ¡;¿ /?'øre .~ Sbo 1t2.~~rr:~ ej;¥-~ ú..... c.Þ(¿("/~G,a, ún/U eo 1,11/3/ Ruft.. .3(¿~.''lÍRlcd "z:!¡¿4vd ~ Cbl-/'i/' "u,# /'<"1 ift..,i If> cIe..us.f) >'IOCO' ~';5~.þ C:DI-c6).,.$-- c o z o -I :e XI -I m [ Y N Y N Z -I J: en » :::tJ m » ( \ Commentsllnstructions: ~ ,§TAf,rD:Ar-t<-Ð pA-f<.A-<S;, r2...--·wn~ , ~~" -"AD not appruv-e..ct .. - , iO -403 cu~ll ~ r-<:Q'ol1 Cld.ct(~l1'(iY1CLfJ 'n.fo r-eo'd1 p-rìoý ·w ë.3)~P'YLY-Q_'1.. '" c:\msoffice\wordian\diana\checklist (rev. 11/01/100)