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200-048
1 Christianson, Grace K (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, June 10, 2025 8:59 AM To:AOGCC Permitting (CED sponsored) Subject:FW: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Follow Up Flag:Follow up Flag Status:Flagged Operator is requesting to withdraw these sundries. Andy From: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Sent: Thursday, 5 June, 2025 10:11 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Byrne, Jan <Jan.Byrne@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Andy, et al, This new interpretaƟon of 20 AAC 25.112(c) and the requirement to P&A each zone within the same pool is a signiĮcant change from what was deemed acceptable by the AOGCC in the past. This has led to hal Ɵng the execuƟon of these 1D P&A operaƟons. ConocoPhillips Alaska requests that our current sundry applicaƟons are withdrawn for the following wells: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) Based on informaƟon presented by the AOGCC at the AADE/SPE luncheon meeƟng on May 22, 2025, ConocoPhillips does not agree that this new requirement will achieve the stated goals or mi Ɵgate the risks menƟoned. We will request a meeƟng on this topic and its implicaƟons aŌer compiling data for discussion. Thank you, Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1D-138 (Sundry 325-171) RBDMS JSB 061225 2 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, May 28, 2025 2:58 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jan, Regarding: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) In reviewing the three KRU 1D West Sak abandonments, the proposed work does not meet the requirement of 20 AAC 25.112(c). I do see that there is an exisƟng plug within 50’ of the shallowest perforated interval, but leaving all the perforated zones open to each other does not conĮne all hydrocarbons to their respecƟve indigenous strata and prevent them from migraƟng into other strata. As such, I will not be recommending these sundries for approval. Jack and I are available to discuss this further. Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: KRU West Sak Oil West Sak Oil- P&A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6543'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email:Jan.Byrne@conocophillips.com Contact Phone: 907-265-6471 Authorized Title: Staff Intervention Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6/1/2025 3.5" Baker GBH 22 Seal Assembly No SSSV 6532' Perforation Depth MD (ft): 5944'- 6064' 6502' 3674'- 3768' 4189'5.5" x 3.5" 13-3/8"79' MD 110'110' Length Size Proposed Pools: L-80 TVD Burst 5795' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 200-048 P.O. Box 100360, Anchorage, AK 99510 50-029-22957-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 5793' / 3562' No SSSV Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY KRU WSAK 1D-138 4200'5828'3587'5828'0 m n P 2 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.03.26 08:27:42-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 325-171 By Grace Christianson at 9:10 am, Mar 26, 2025 JJL 4/25/25 10-407 AOGCC witnessed tag TOC and MIT-T to 1500 psi. AOGCC witness casing cuts before top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut. Variance as per 20 AAC 25.112(i) for alternate reservoir plug in confining zone. X XX DSR-6/3/25 March 25, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, ConocoPhillips Alaska, Inc. presents the attached 10-403 sundry for KRU West Sak injection well 1D-138 (PTD 200-048) to be Plug and Abandoned using the existing WRP at 5828’ as part of the reservoir plug (Slickline will dump bail ~35’ of cement on top of the WRP to complete the reservoir plug). The WRP at 5828’ is 116’ MD above the upper perfs at 5944’. The WRP passed an MITT to 2000 psi and a DDT on 1/25/25. The tubing was successfully drifted with a 2.69” WRP dummy down to the existing WRP on 1/5/25, but multiple tight spots were encountered at shallow subsidence depths (187’, 269’ & 386’ RKB). The multiple tubing restrictions increase risk of getting the existing WRP stuck if attempted to pull for a deeper set reservoir plug. Additionally, the liner condition below the WRP is unknown and a deeper set plug may not retain integrity. With the current WRP passing both positive and negative pressure tests ConocoPhillips believes it is less risk to move forward with the P&A using the existing WRP at 5828’. ConocoPhillips Alaska, Inc requests the AOGCC allow that the existing WRP at 5828’ may be used for the reservoir plug on 1D-138 as outlined in the following sundry application. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Staff Intervention Engineer ConocoPhillips Alaska, Inc. 1D-138 P&A Procedure Date: 3/25/25 Network Number: 10460680 Prepared by: Jan Byrne 808-345-6886 1 CContents Objective ....................................................................................................................................................... 2 Current Well Status ....................................................................................................................................... 2 Job Design Data ............................................................................................................................................. 2 Design Envelope ............................................................................................................................................ 2 Volumes ........................................................................................................................................................ 2 P&A ............................................................................................................................................................... 3 Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T ................................................. 3 Slickline – Drift for Eline ............................................................................................................................ 3 Eline – Punch holes in tubing and perform injectivity test ....................................................................... 3 Cementing Unit - Pump Tubing x IA Plug to Surface ................................................................................. 3 Surface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar ........................................ 4 Appendix ....................................................................................................................................................... 6 Tubing tally ................................................................................................................................................ 6 Liner tally ................................................................................................................................................... 7 Schematic .................................................................................................................................................. 8 2 OObjective In 2022 a 1D-Pad mechanical well review identified six wells to be Plug and Abandoned (P&A) due to single casing well designs, mechanical integrity damage, and subsidence damage. 1D-138 has a known surface casing leak at ~174’. Subsidence drifts report increased tubing restrictions. The objective of this project is to P&A 1D-138. It is recommended that a full P&A be performed by cementing the well to surface and excavating 4 feet below original ground level, removing the wellhead and cellar, and backfilling with gravel/fill to ground level. As subsidence driven deformation continues, the risk of losing well access increases with time. This non-rig P&A ultimately saves money and mitigates future risk to the company. Current Well Status x 10’ OAL length sleeve over shallow leaks in 5.5” casing x Leak at ~174’ in 5.5” casing. 0.3 BPM LLR at 50 psi x 2.69” Weatherford WRP set in 3.5” liner at 5828’ (7/6/2014) x Able to drift 2.69” dummy plug to WRP at 5828’ on 1/5/25 x Passed MITT to 2000 psi on 1/25/25 x Passed T & IA DDTs on 1/25/25 Job Design Data x Last SBHP: 2318 psi at 3418’ TVD on 4.20.22 x Reservoir temperature: 70- 75°F in West Sak D sand x Fracture gradient: 0.67 psi/ft x Fracture pressure: 2462 psi (.67 x 3790’ TVD top slot) Design Envelope x Tubing 3.5”, 9.3 lb/ft, L-80 x liner: 3.5”, 9.3 lb/ft, L-80 x Production Casing: 5.5”, 15.5 lb/ft, L-80 x Wellhead: Vetco Gray horizontal x MASP Normal WOG Volumes x 3.5” Tubing from 0’ to 5750’= 50.0 bbls (.0087 x 5750’) x 3.5” x 5.5” Annulus from 0’ to 5750’= 68.4 bbls (0.0119 x 5750’) x Diesel FP, to 2000’ TVD = 2158’ RKB = (.0087 bbl/ft x 2158) = 18.8 bbls 3 PP&A P&A Plug #1: Reservoir Plug Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T 1) MIRU Slickline. PJSM. 2) Dump bail 35’ (0.30 bbls) of 15.8 class G cement on top of the WRP at 5828’. a. This will put TOC at ~5793’. b. The minimum required cement dump bailed on top of a plug is 25’ (0.22 bbls). 3) WOC a minimum of 48 hours before proceeding to the AOGCC witnessed Tag and MITT. 4) RIH for AOGCC witnessed TOC tag (estimate ~5793’ RKB) and perform MIT-T to 1500 psi. Record Results in WSR. a. Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 5) Only proceed to next steps if MIT-T passes and TOC is acceptable. P&A: Plug #2 Slickline – Drift for Eline 1) Fullbore drift tubing down to ~5754’ to verify Eline will make it down with punches. 2) RDMO, ready for Eline. Eline – Punch holes in tubing and perform injectivity test 1) RIH with tubing punch to punch holes in 3.5” at ~5745’ (10’ above DS nipple at 5755’). Punch sufficient holes for 2 BPM circulation rate. Do not punch through 5.5” casing. 2) Verify injectivity through punches. Pump down tubing taking returns off IA to tanks. Need to monitor return rate due to leaking 5.5” casing at ~174’. Document return rates and if losses are observed. a. If 2 BPM circ rate is not achievable punch more holes and repeat injectivity test. b. If significant losses are observed cement calculation may need to be modified. c. 1500 psi Max pump pressure. 3) RDMO, ready for Cementing. Cementing Unit - Pump Tubing x IA Plug to Surface Cement Volume Calculations: • Volume in 3.5” tubing: (5745’-0’) x 0.0087 bbl/ft = 50.0 bbls • Volume in 3.5” x 5.5” annulus: (5745’-0’) x 0.0119 bbl/ft = 68.4 bbls • Excess: 25% • Total volume: 50.0 + 68.4 = 118.4 x 1.25 = 148.0 bbls 1) Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Bryce Hinch 307-359-0067). The job is designed for 148.0 bbls of ArcticSet 1 (AS1) cement. 4 2) Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3) RU HES Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3.5” x 5.5” annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4) Open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5) After circulation to IA is confirmed batch up AS1 cement. 6) Line up to pump cement down the tubing, taking returns from the IA. 7) Follow Pump Schedule below: 8) 20 bbls fresh water spacer ahead 9) 100 bbls (2x Tbg) surfactant wash. 10) 100 bbls fresh water spacer. 11) 148.0 bbls of Permafrost Cement (AS1) to surface in tubing and IA (including 25% excess). 12) After approximately 118.4 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud density scale to confirm proper weight Permafrost Cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 13) After good IA cement is seen at surface, shut down pumps and close in the IA valve. 14) Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 15) RDMO SSurface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar 1) MIRU required equipment. 2) DHD to perform drawdown test on tubing and IA. 3) Remove well house. 4) Bleed off T/I to ensure all pressure is bled off the system. 5) Remove production tree in preparation for excavation and casing cut. 6) If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 7) Cut off wellhead and all casing strings 4 feet below original ground level. 8) Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 9) Send the casing head with stub to materials shop. Photo document. 10) Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 1D-138 PTD #: 200-048 API #: 50-029-22957-00-00 AOGCC witness casing cuts/TOC before top job commences. - JJL 5 11) Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12) Obtain site clearance approval from AOGCC. RDMO. 13) Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment. 6 AAppendix Tubing tally 7 LLiner tally 8 SSchematic Current Completion Proposed P&A 1D-138 PTD# 200-048 Proposed P&A Schematic 13-3/8” 62.6# H-40 Conductor @ 110' MD 5.5" x 3.5" 15.5# L-80 Production Casing at 6532' MD 3-½” 9.3# L-80 Tubing at 5795' MD WRP at 5828' MD West Sak D sand upper perfs at 5944' West Sak D sand upper perfs at 5944' Seal Assembly at 5793' MD Reservoir Cement Plug Slickline dump bails 35' of cement on top of the WRP to place TOC at ~5793' Tubing and IA cement plugs from punches at ~5745' to surface Calculated TOC (5.5 x 3.5" x OH) = Surface SCMT run from PBTD to SBR on 6/4/2000 (5.5 x 3.5" x OH) TOC = 5794' MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ 7(Z~'(l ~' FROM: Bob Noble Petroleum Inspector r~ l~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-138 KUPARUK RIV U WSAK 1D-138 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1D-138 Insp Num: mitRCN100718145335 Rel Insp Num: API Well Number: 50-029-22957-00-00 Permit Number: 200-048-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! IDa3s ' Type Inj. I N" TVD 3559 IA i 160 1760 1700 1700 P.T.D zoooaso' TypeTest sPT Test psi I76o ~~ OA Interval a~TST p/F P Tubing _ Aso Aso Aso Aso Notes: ~,~;~~ reC, ~c~ ~5~' 1 ~~,` A '~~, 5? > i t~S, d+" ' Thursday, July 22, 2010 Page 1 of 1 • i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1D-138 Run Date: 3/3/2010 March 17, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-138 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-22957-00 Injection Profile Log 50-029-22957-00 ~, ~. 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. U Z ~-' Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr [p :. ~o~ -out 19~(~-3 Date: MAR `' `~ 2010 r.~.~,, .~r~ ~ ~ :~ t~ .~~ Signed: • s ~ ~~ ~~ ==- -~~ ~ ~ ~ ~Pr.~Acaier~ ~inc~iv<as~c ~~atwicks, ~r~c. To: A~CC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Ataska 99501 (907) 859-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProQctive Diagnostic Services, tnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245~8952 1 J MTT Report 17-Jun-09 2) t~ = ~- ~c~ ~ ~~ 1 D-138 i ~a ~~ ~ ) ~ Signed : Print Name: Date _ _ _ _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERMATIONAL AIRPORT RD SUfTE C, ANCHORAGE, A6C 99518 PHONE: (90~245-8951 Fax: (907)245-88952 E-PAAIL : _,: . - ~ . _ WEBSITE : _ 1 Report 50-029-~2957-00 ~~ '~~~~~:~ .~~a~ .~ ~~ 20D~ .~~~y ~~ C:~Documents and Settingl0wner~DesktoplTransmit_Coneco.docx • ~ ~ Memory Magnetic Thickness Tr~l Lag Results ~ummary Company: Conoc:oPhillips Alaska, Inc. Well: 1D-138 Log Date: June 17, 2009 Field: Kuparuk Log No. : 10564 State: Alaska RUn No.: 3(2nd MTT) API NO.: 5(7-029-22957-00 Pipe1 Desc.: 3.5° 9.3 Ib L-80 EUE Top Log intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 214 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM 7op Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 214 F#. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvf.: 110 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage -nspection COMMENTS : This MTT data is tred into the Mandrel Hanger ~ Q' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to th~e #ota! thickness of inetal of the 3.5" tubing and 5.5" production casing, as well as influence from the 16" conductor pipe. Passes at 5Hz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the SHz and 10Hz passes selected for analysis in this report. COMPARIS~?N TO PREVIOUS M1T LOG RESULTS : ._. A comparison of the current 10Mz pass to the previous 10Hz pass (September 26, 2006} indicates na ' significant Ioss of inetal thickness during the time between lags. Indieations of a s'rgnificant increase in metal volume are indicated over the interval (0` -11'). This increase in metal voiume is believed to be associated with the Vecto-Gray tubing hanger (0' - 28'} instal{ed on April 28, 2008, ~fEer the previous MTT log ' (S~ptember 26, 2006}. A log plot overlay of the average metal thicknesses rer:orded by the MTT for the current and previous log is included in this report and the most signincant areas of inetal loss indicated in the current and previous logs are lis#ed in the tabte below. , Maximum Meta) Loss ~~ 2009 2006 Desctiption 10' -16' 456 696 Genera! circumferenaal meta! loss ' 35' - 38' 4% 4% General arcumferenaal metal foss 50' - 68' 3% 49b General dreumf~erencial metal loss In the 2006 log, a single calibration taken witftin the conductor pipe was applied to the entire log interval. This resulted in an indicativn of less meta! below the conduetor, ~elative to the interval including the conductor. The current data set was processed using calibrations from both zahes, eliminating the appearance of inetal loss betow the conductor pipe. In order ta support a more consis#ent comparison ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDSCamemorylog.cam Prudhoe Bay Field Office Phone: {9Q7} 659-2307 Fax: {90?) 659-2314 u~ ~pv-Uc.~~ r~2t~ ' • ~ between #he current and previous log, the previous data set has been re-processed to include a calibration ' reference from the zone beiow the conductor pipe. A much steadier logging speed (20 fpm) is observed in the current log than the previous log, enhancing the stability of the tool response to the metal volume surrounding it. The added stabifi#y and reliabitity of the data , recorded at steady 20 fpm is believed to be the cause fvr some of the slight variance between the 2006 and current log results. INTERPRETATION 4F MTT LOG RESULTS : ~ The MTT log results cover the interval f~om surface to 214'. Changes in metal volume are reia#ive to the calibration points at 70' and 150', where the readings are assumed to represent unzlamaged pipe. All other ' readings are relative to these reference points, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. Log plots of the entire 5Hz and 10Hz passes and an overlay plot of the average metal thickness recorded by ' the MTt for the 5, 8, 10 and 12Hz passes are included in this report. A maximum overall metal valume loss of 4% is indicated in tubing pup joint 0.3 (10' -16') and joint 1(35' - 38~) in the 10Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the , tool is responding to, which includes influences from the 3.5", 5_5" and 13.375" pipe. tf a1! of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of #he metal loss indicated could be from either the 3.5" tuhing or 16" conductor. ~ , i ~ n ~ ' ~ Field Engineer: G. Etherton Anatyst: HY. Yang & J. Burton Witness: R. Ober 1 RroActive Diagnastic Services, Inc. f P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-maiL• PD5~amemorylog.com ' Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 1 ~ P~eoAcdve Dlwqr~nsdt SE~s, Inc. Database File: 1d-138.db Dataset Pathname: 1l1/1lcomp Presentation Format: comparis Dataset Creation: Sun Jun 21 18:01:44 2Q09 Charted by: Depth in Feet scaled 1:150 -50 -50 0 ~0 4Q 60 Comparison to Previous ~ Log Overlay 1 D-138 June 17, 2009 and September 26, 2006 Delta Metal Thickness 2009 (10Hz) (%) Delta Metal Thickness 2006 (10Hz) (%} 2006 (1 Tubing ~Iled on 50 50 Bottom of 16" 80 ~ 100 12Q 14~ 160 180 ~006 MT 2009 ~00 Delta Metal Thickness 2009 (10Hz} (%) Delta Metal Thickness 2006 (10Hz} (%) •1 D-138 Recorded Magnetic Thickn~Log Data -10Hz Pass (Surface to 214') June 17, 2009 PwoAcdvE Diwqwsric Semrlcq Inc. Database File: 1d-138.db Dataset Pathname: 10HzPas.1 Presentation Format: 3 scale Dataset Creation: Sun Jun 21 16:00:29 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 3 MTTP01 (rad) 13 0 Line Speed (ft/min) 200 -5.8 MTTP12 (rad) 4.2 Speed~_--f --f --~-f ~ Tree I Pup 3.5" Tubin Collar ~-- +~ 4 ' ~ Pup 3.5" Tubing Collar . :1~ 4% Metal Loss ~ Pup 5" Tubing Collar ~ ~ 24 Delta Metal Thickness Jt. 1 4% Metal Loss 40 -- ~ - 5.5" Casing Collar 5" Tubinq Collar ~--! ; ~ 3% Metal Loss 60 Tubing Jt. ~ of 16" Conductor __ -~- ,~~. - - -- -~ r - ~ _ ~ - ~.__-- 5" Casinq Collar •1 D-138 Recorded Magnetic Thickn~ Log Data - 5Hz Pass (Surface to 214') June 17, 2009 PwAc.we oL~q,.os.~~ sE.v{ca, Inc. Database File: 1d-138.db Dataset Pathname: 5HzPas.1 Presentation Format: 1.4 scale Dataset Creation: Sun Jun 21 13:38:38 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.4 MTT Phase Shift - Sensor 01 (5 Hz) (rad) 11.4 0 LSPD (ftJmin) <00 -7.4 MTT Phase Shift - Sensor 12 (5Hz) (rad) ~.6 Tree r~ ~ ~ ; ~~ - i Pup _ ~ ~ pUp i ~ ~~ Metal Loss Pup ~p Defta Metal Thickness Tubing Jt. 1 1% Metal Loss 40 -- - -- Casing Collar Collar ~~ -- _ _ _ ___ _ __- --- 3% Metal Loss 60 Tubing Jt. 2 Bottom of 16" Conduc ~z, 8Hz, 10Hz and 12Hz Passes Del~etal Thickness Overlay 1D-138 June 17, 2009 PrmAr.itve DlwqriasTtc Sewvlcs, Inc. Database File: 1d-138.db Dataset Pathname: 1/1/1/overlay Presentation Format: comparis Dataset Creation: Sun Jun 21 18:24:11 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2fl09 (12Hz) (%) 50 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness ~009 (8Hz} (%) 50 -50 Delta Metal Thickness 2009 (5Hz) (%) 50 a ~a 40 60 sa ~ 100 120 144 160 18d ~~ -50 Delta Metal Thickness 2~09 (12Hz} (°/a) 50 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness ~009 (8Hz) (%) ~ ~ 50 -50 Delta Metal Thickness 2009 (5Hz) (%) 50 KUP 1 D-138 r ~OI'lOCO~'11~~ip5 ~ Well At waroo2 tri6utes xn da e s~ ~us r.om M ryPe Max M le d~ ND ma s~ TD ) al,~ti".' ~'i ` 5002922 95700 WESTSAK INJ PWI 67J0 5,029.30 6,5430 os s:w ~n ~~n + ~ Co 1 e ~SV: NONE 0 7/1/2008 o Last WO: n tl 31.09 B Nemae e 4/29/2~00 ~c-nauai M~optlon Last Tag: SLM j 5,936.0 End re 12/5/2008 Rev Reazon: TAG FlLL ~e 12/8/2008 Casln Strin s ca o es«yaon rmq o M1 o sm+u Inl ro pnce~ s e~ oepn 1~~1 sec oe l 1~& 1 M~q ~ s~mp r mra CONDUC TOR 1 6 15.062 0.0 110.0 110.0 62.58 H~0 WEIDED PRODUC T10N5-5" 5 7/ 2 4.950 0.0 5,8024 3. 568.5 15.50 L-80 BTCM P ODUC TION3.5" 31/ 2 2.992 .802.4 6.532.4 4. 189.5 9.J0 L-80 EUEBRD T bi Stri u l~W~pD n s esat on ng Pn) St rp ~o P~) ~bp~nKD) s e~ (~g) aet DepUi (~8) 1 rkg (~~9 Strkg ~~ TopThrtl TUBING 3 7/ 2 2.992 0.0 5.795.0 3, 5632 9.30 L-80 EUE SRD Ofh I M l All J bi l T R 8 Pi h t er n o a op Deplh (~) awe TopYW u n : un ~ w a s c. ToP (ltl(B) (~B) P) CommM IM Dete ID pry 28.0 28.0 -0.71 H ANGER VETCO RnV TU NG H ANGE 4/28I2008 5.500 5,761.0 3,539.6 45.61 G AS LI CAAACO/K8G -9/1/DMVA lll Com ment: STA 1 4/29f2000 2.900 CONWCfOR, B,~$P.O 3,554.0 44.60 N IPPLE CAMCO SNI PPIE 4@9l2b00 2.813 110 5,788.0 3,558.2 44.31 S EAL BAKER GBH-Y l SEAL AS SY 4292000 3.000 Par/ora dons roP rrw~ ea, Rvq a ~ ~Pp~si eun~lu~ I~N IKKBI Zore Date Isn... ry pe Cm unert GASLIFf, $,JM}.O 5,983.0 3.6 3.9 3,703.6 WS D, 10.138 7I512000 4.0 AP E F 60 Deg Ph, 31.1 UJ HMX 5.161 6,018.0 6,064.0 3,733.3 3,768.1 WS C, W B, 6l28l2000 4.0 IPE F 60 Deg Ph. .5" H SD DP 1 D-138 Nobes: t~aie ral 8 11/74200 6 N TE: PATCH WELD ON IA SEAL WELD CASING AND MAN D EL HANGER. WEID ED 7W0 6' BANDS AND td-2' SLEEVE NIPPLE,5,182 SEPL. 5,]88 PROWCTION s s, s.aoz ~F. 5,946b,983 IPERF. 6,018b,066 PROWCTION 3 5", 6,531 TD 116138). 6,543 Jun 14 09 47;12p I'D5 fnc 907 fi 14 _ - ~.. -- ~ ARCtJ Alaska, t~c. 5unm~irv nt atlarmc s~c~d co:~m~v 7`L1BiTdG TabPrn~ vr Liner Descriptian p.22 wEr.[.: ~~ y~ ~fA7'E: 4128100 1 G1F '1 PA~ES ~ iTEMS COIfAPLET~ DESC6tiPTK)N OF ~{2WPM~7 RlFF l.ENGTt~! OEP'C'H • ~ ~ ._~~ NORDIC RtG #3 RT ta LDS T 28 35 ! 28_35 Vetco-G~ray Tbg. i~langer Wf 3_5" EtlE 8rd pup 3.4Q' 8~ Nar:ger1.2d 4.Ei4 28.35 32.99 P'up 3.S" 9.3i~ L-80 EUE $rd Mod Pups 8.12 & 8.~2 14.24 32.9~ J~ i13-188 3.5 9.3it L-8f3 EtJE 8rd Mai tb9- 56~.42 47.23 3_5" 3.3# ~.-8D EUE 8rd Mod f~up Xt7 &~ti rtwd lf Eue Box 14:~7 568t.6~ GI.iVF 3.S`" % 1" Ca~»CO'KSts-,Z-9" w! ~V-Int~grai tatah 8.~0 5702.32 Pup 3.5" ~3.3~ ~-8tt EUE Std Mod Pup XO ~fl mod X Eue t~n i4.19 5708.02 SL i~2 3.5" 3.~# L-80 Eue 6 rd Mod tbg. ~ 37.~5 57'23.21 3.5" C~nCO `DS' LsndEn nippfe 2.$i3 no ofi1E 1,t3 ~75A.6fi J~. $1 3.5" 9_3# !.-$0 EUE 8rd 1~Qd fbg. ~4.40 5T55.79 Pap 3_5' 9.3tt L-80 EUE 8rd A4~ F~up 6.12 5787.~9 Locatc~' 8akcr &fl-40 CiBH-22 Lacatar Spotted 1' up 1.83 5793.31 SA Seat a.ssernbly is 11.9(3' T~ c~f 8a i0 S8E ~ 57~0" s7flS_i 4 -- Nd+rta~tks: Sit~ng Wesghts with B1oCics. 62K7,~ Up. 40K# Un, 20K# Blocks. Rsn 1$3 j oints ai tu6in g. ~riSerl tubir~. ~LMs_ 8 h~ wrilh 2.~~' nlas6c fahbik tlsed ArctiC ~rade API M o~d No L~! th~ead compaund tuF ap corx~ct€ons. Tubiru~ is non-cao~ted. -_ __ Norriic Rig #k3 Dr~n,~ 3upervisar: M C. tieim _~ Jun 14 t39 47:12p PDS I~c ~~. casar~~ o~~.~i~. 5-2f1" X 3-~/2" Ga~ Liescr' 4n ARGQ AlaslCa, Inc. Su6st~arv d AUantic Richfieki C[xns~a so~ s ~ ~ p.2a KRIJ 30-'i38 [}ATE: 4125/2~l1i4 1 Cl~ t PAGES # t~'E6145 Cc3afPCF1'E DESCRlPTIC7td i3F EQU13~fA~t~'f R 1N c~tir,~fi 3,1E~'t'H . 7dPS -.43 " -.A3 -.A3 -_43 3 -.4.3 __.._ -.43 NC~i2[31C R'~'f0 LANCt1NG R1N~G ~tl,:~[7 -.43 5-11~'" Gray Gasing hang~r w~ pu 3.13 30_Q7 Jt 313~33~ ~a-t 12"' 15.5#, L St3, BTC-P+1tad Csg 944.7d 33.20 5-112' 1`arn Por# Cc~11ar ~ ~..... _ $.2~ 977_A4 ~t 20l-312 5-f/2' 15.5#, L-8~, BTG-l~od Csg 47£d3.7B 98G_~i3 5-1/'L" 6akerCrUSSOver up6~Q0" OQ. 4_Fr37° ID ~t0.i2 5T80.U1 Baker i2' SBE w! 5" 00, 4" il3 't2.36 ' Sl90.13 3-1f2°.9.3#, ~.-8t1, Ec:e 6 t~ Mod P 44.~ 5602.99 JPs #4-23 3-7f2". ~.3#, l-9(3, Eue 8 rd Mod Tbg 619.59 5813.Of 3-itZ" ~lfleaf#-erFord ianding collar 2.35 64~2.$0 jYS ~3 3-i 12", 9.3#, L-8Q, Eue 8 rd Mad 7bg 31.-15 6435_55 3-R12" W8~8thertord Flaat co~a~- ~ue 8rd bax x pin 1.'!8 64$7 {3(1 JYs #~ S 2 3-1 t2", S.3#, R.-~0, Eue 8 rd Mad Tbg 63.~2 &46$.SB 3-if2" WeatherfoM F~oat shos ~u~ 8rd box. Z.20 4i52~~U 853,2.00 , Centratizers 3-1/Z" - E~un two 3-112" X 7-518" RCY'f"CC/ Shcd Spirnf S1ad4 Cefittalizers - ---- perf~. Place st cd?at in the cent~' ui ~ch jt. Let centrBkAer fMsF betuveen it an~ itse coltars Cen3ratizars 5-ii2" f~XS 5-~12" X 7-718` 8ow5p~ng CentratixBrS 2 perfjt far 5U0' a~~us r - ~ crossover. Stop ring in midd(e oF joint IeEting centralizar fk~af t~fwean c4El ~r . ar~d s~ rinq_ Jaints 201 itiru 212_ Plar,e i Bowspring eu~ery :~oints 295, 218.229,224,22~,230.233.236.239.242.2~€5.248.2~1.2~.257 ~6U,263.286.265.272,275,2fi$,281,284,28~,294.2~'3.29B.299.302, 3q5.3013,371{312,373.~ 3fT.32Q.3Z~.326.329. ~ ~,32 F'cetrt~rk.~ Slrin~ Wcrir~ht:, ~'t BIrtck:.: ??Ift~ t1p, ??iG# C?ct, 6K~/ Btodc:.. ~n ??? joi nts ~ casiru~ - v~ casmg, if lt~Pt~r Wip) 1.tid(' FOf J_5° 15~ 4,tf'LS~ tOC ~.5'" ~16StK P"c+t'~lt Used ArcFic ~!r~de APi Modifisd No Lead ihread crn»~aund on atl wnne:iions. 7ubinr~ is noR-t~ated. ~(~ilc Rlg tf3 Dr~-g Sripervfst>r: Oonstd L. Wa: ter • MEMORANDUM TO: Jim Regg ~ ' ~~+llz~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 3l, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-13S KUF'ARUK R(V CJ WSAK ID-138 Src: b~spector NON-CONFIDENTIAL Reviewed By: P.I. Suprv (&. Comm Well Name• KUPARUK RIV U WSAK 1D-138 API Well Number: 50-029-22957-00-00 Inspector Name• Bob Noble Insp Num: mitRCN071028042632 Permit Number: 200-048-0 Inspection Date• 10/26/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. . __ _ __ _ -- Well I~-F3s TypeInj N TVD 3ss9 IA Iso nao 16so 16so.. P T. i iaooaao TypeTest sPT -.Test psi ITao OA _ ~ __ I ._ ___.._ Interval, orH>rR P -' Tubin aao azs 390 ! 3~0 ~ ~ _... NOteS: MIT-IA post production casing repair. Well was S/I .~ ,R _...._. _, Wednesday, October 31, 2007 Page 1 of 1 . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, AlÁSKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 07 333 West 7th Avenue, Suite 100 SCANNED JAN 1 620 Anchorage, AI< 99501 &OÓ-04- ß Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were fIrst fIlled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was 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 ofform 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem "VeIls Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 10-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na e e MECHANICAL INTEGRITY REPORT - ....... -dOO --0 q c& :. ~ G 2 .s ~ ~;._ :: ~ : OPER [. FIELD - c.. 'V þt.. \ \L \è 0~ S Í<;""Eil NUKB ER \ \) - \ ~t( ::CUD G;'.:'::: l11'j):-;MJÓ '", toLL DATA TD: G:.SL\~ }illu l{;)Ol) TllD i :?:3TD: G:,4~ ~ HI) i--\C)'; 'ì TV!) . Cê.S Ì;:;g: 5(/;)-"*3 Y:J--- s~: 5'lc)O l{[) TVD ¡ DV: ~~ l'1D TVD _ ::":ì e =- : Shoe: <os ~d- MD _ --.1D'-.:;g: slId Packe~ 5~c;Ò MD :.ole Si.ze ~"ì./C(; 2.na TV1); :C?: 5'11 Ò l·ll ;:'iîJ TVû; Set ê. t ~1)3>d <00 \ ß CpOíO~ P er£ 3 ss. Co~ to ~~ ~S S~ '-\ '-\ s,-S <0 ~ ~C7._A1EC,'.-L INTEGRITY - PART !l Annulus Press Test: ~~ 15 nnn 30 mln COI:üI:lents: ...--- :-:ECHÞ_~EC;'-L INTEGRITY - PART ¡ 2 40b':.-~ ~ ~~ ':>~,~ ~ 4\d~~\S Ce!Ilent: Volumes:- Þ..mt. Liner CsgSj()S'-L i DV 't-JI\. CLilt -,lol to cove:!:" ver':3 e~o)o '/..~~}~<>~ c ~,.\ ~\6~ -k,-O~\ ~y V'-\~ t(\~~ 5""00' Theo:!:"ecical Toe ~"--~ ~'\J\.o..-..J~__à.\LV\~-~ (l\.~~~~\\\:\> ,~ ~\\a~ctQ - Sc.k. \"" c;. (4. -;lOCO Ce!Ilent: Bond Log (Yes or No) it:.-<7-- i In AOGCe File -~E::7 ~ ~\~~c~e~ CBL !::valuation, zone ¿Dove perfs Prociuction Log: T~e ; Evaluation (';;¡(~I\\ì~~;¡¡~7Y-<i In: c ) ~¡ 2~iC:~ CONCLUSIONS: ? ar t : 1 : ~~\~~~~ ~ØYv( \";>{ lC;-O(,ø :J.-.,.-...... _ a....L.. '- ;2: . . Conoc~illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 20, 2006 RECE'\IED NOV 2 2 2006 AI ask, Oil & A'. CtHl1tnission nChoflge . Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 " "r· Ii I>I.I"-U::n :,,?t..'F~n:l'J f;,c,(u "i. ~. 'if¡fìi\ .J_. '.;;... f~'~", '-...,' ,~) Dear Mr. Maunder: Please call Jerry Dethlefs or MJ Loveland at 659-7043 or Marie McConnell or Perry Klein at 659-7224 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor Attachments -' . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . REPORT OF SUNDRY WELL OPERATIONS · ~-..........., w _w NOV 2 2 2006 Alaska Oil & Gas Gons. Commission Anchorage 1. Operations Performed: Abandon 0 Repair Wen El. PlugPen'orations 0 Stimulate 0 Other 0 Alter Casing, 0 Pull Tubing 0 Perforate New Pool., 0 Waiver 0 Time Extensioll 0 ChangeApproved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 " " 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-048 . 3. Address: Stratigraphic 0 Service 0 . 6. API Number: P. O. Box 100360 50-029-22957-00 . ", 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 10-138 . 8. Property Designation: ~fG.S'O ~þ ~Þ.Þ" 10. Field/Pool(s): Kuparuk River Unit ¡4'p1.. It. Kuparuk River Field 1 West Sak Oil Pool . 11. Present Well Condition Summary: Total Depth measured 6543' . feet true vertical 4199' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 13-3/8" 110' PRODUCTION 5689' 5-1/2" 5790' t::\ L) ,\ ~\.(';) ¡\ 0. \.c, ~Q '\ LINER 742' 3-1/2" 6532' "'f \<" ~v S ~-\. Ii'-\. -o. o...) L C;... S"Ç::...,,\ \)~ ,C·:. C....\. ..\-~~ '/;.. a g....t~<1~ \){\~ _ (J I". Perforation depth: Measured depth: 5944-5983, 6018-6064 true vertical depth: 3674-3704, 3731-3768 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5795' MD. Packers & SSSV (type & measured depth) Baker GBH-22 5788 no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Productioll or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation Subsequent to operation 14. Attachments 15. Well Class after proposed Work: Copies of Logs and Surveys run E:xploratory 0 DeveloPmént 0 Service 0 . - 16. lJ\IellSfafus afterproposectwork: . ",.'," ,'," Daily Report of Well OperatiÞns_X \^,h~¡:ÎI.n qilD GasD WAG 0 GINJD WINJ0 . , 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: 305-226 Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Nanie MJ Loveland Title Problem Wells Supervisor Signature Phone 907-659-7224 Date 11/19/06 ., " ~KI IIUIS 6Ft IEC 1 4 2D~ \L.lo.. ~ /(. s~·~ Form 10-404 Revised 04/2004 0 RIG 1 N A L 1 . SUbmi~~;-¿:¥ . 1 D-138 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 11/6/2006 Cutoff 12' 1" of conductor. Found hole in SC @ 6' 10" below top of mandrel hanger. T/I=SIIO. Pulled VR plug from opposing side of the valve and installed purge jewelry. Rigged up N2 purge across IA. Cut a l' 7" window out of the conductor 3' 10" down. Cut a second l' 4" window out of the conductor 10' 6" down. Split conductor in half and removed a total of 12' 1" of conductor. NOTE - New conductor needs to be 11' 7". 11/14/2006 Patch weld on IA. T/I = SilO, Rigged up purge hoses and purged N2 out hole in lA, Seal welded casing to mandrel hanger. Welded two 61\ bands (5 1/2", 15.5#, L"80) on to casing. Welded 10' 2" of?", 26#, .362, L-80 casing. Total patched area is 10' 8". 11/16/2006 MITIA - Passed, (Post SC patch weld). T/'=SI/O Installed VR plug in opposing of IA. Pressured up IA to 1800 psi with .5 bbl diesel. T/I = SII1800, started MITIA. 15 mín = T/I = SII1760, 30 min - T/I = S1I1750, 45 min - T/I = S1I1750, 60 min - T/I = S1I1750, Total loss of 50 psi. Bled to 0 psi. T/I = SliD 11/18/2006 Installed new conductor. TlO = SilO Assisted welders installing 11' 7" of 13 3/81\ 68# .480 conductor. Wrapped top of conductor with cosmolien paper. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased HolelOpen Holel Mechanical Logs and lor Tubing Inspection(Caliper I MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951 B Fax: (907) 245-8951 r:T' '- ,," ~ ~,~\¡¡;.,.) ",;':'¿'A.';''' ~è, 1J 2J 3) 4) 5) 6) 7) 1 Report 1 D - 136 MTT Report 26-Sep-06 U.:rC- 900 -O'-IC:J 1 Report 1 D - 137 MTT Report 26-Sep-06 U::r.e- J(jJ-o'-/7- 1 Report 1 D - 138 MTT Report ~Sep-06 U J. C. é)OtJ - r!!i) 1 Report 1 D - 139 MTT Report ~ 26-Sep-06 U:r. C- 900 - 0'-/9 RECEIVED Print Name: o/J~ QJA r~:")tì '^ p m,(\\^ \1\ t2 {)JA SEP 2 9 2006 Date· . . Í\i-.a IJiI & Uas t,;{JI\S. Cull fml5SlOIl Anchorage Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\OO _ PDSANC-2006\Z _ W ord\Distriblltion\Transmittat Shccts\Transmit_ OriginaJ.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 10-138 Log Date: September 26, 2006 Field: Kuparuk Log No. : 8054 State: Alaska Run No.: 1 API No.: 50-029-22957-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 110Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 192 Ft. (MD) Inspection Type: Assess External COffosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 7% circumferential metal loss is in the interval between 5' - 7'. A 6% circumferential metal loss is recorded in the interval between 10' -16'. A 4% circumferential metal loss is recorded in the interval between 35' - 37' and 52' -59'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 13.375" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey Analyst: M. Tahtouh & J. Burton Witness: J. Brake I / p,Ci" Boy 1:i69¡ Staffo¡cJr TX 7749:7 Pn:JÞ·,ct!ve Diagnostic ~)ervicesf IrJc. E-mail: '.J! rJrudhoe Bay FiE;:1d ()ffice Fax: 659-2314 u:r C-- &D0 -0 '--fõ · Magnetic Thickness Too (10Hz Pass) g p~ DiAqNOSTlc SERvicEi" INC. Database File: d\warrior\data\ 1 d-138\1 d-138. db Dataset Pathname: Kuparukl1 D-138Jrun1/P1 OHZ.1 Presentation Format: 24SCAL -1 Dataset Creation: Thu Sep 2807:23:51 2006 by Calc Sondex Warrior VTO Charted by: Depth in Feet scaled 1150 -50 Delta Metal Thickness (%) 50 24 MTTP01 (rad) 124 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 --+- r Tree 1 1 I 0 -Hange -L_LL 5" Collar Pup Jt. Jb" COllar r--7% Metal --j--o Pup Jt. 1 Los =+= ;~~=---- --- -I---- ¡.5" Collar -.-- t--- --,^ -- -- - ^_M Pup Jt. - - 6% Metal - I--- I Loss- - -" .5" Collar ~ 20 r-- ... - - - ~ E" r--- i ,- ,-- ----- -- __m --"'- _nn_ --- _M.,__" .---- - -- - 3.5" 1-: - r-- - - Joint 1 - - --- ,-- - ---- ,---- Í'- --- c--- - ) : --c;; - ..l I ~ __4% Metal_- ....., -~ 1 ____M___ r-- -- --' --- -- -- Loss 40 ~ 1 ,---- - r- --- .COllar- - - :'-3.5" Collar -""- _1 ----- ____.n --- ~=:-- ------ _n_,_ --- __n____ 1--- -- - -~ ¡:=:::: ,.. ~ -==' ~-4% Metal- ... -- r--- 1 ,~ r--- -- ;""--- I -L Loss I' - \ r-- r- :: 60 i=""" ~ - i""'""" ¡- r- L' --.::: 3.5" b- -- - ---- ---. ---c -"-'- - <-- lL- l Joint 2 - ~ r- __n_' - -- ------- 1-- - --,-- !-'~ ". ~ ~ Line ,Speed I I::- .± 1- ..... r:; -'-- ~ 1--- 1---- - 1-- 1 _I I r-- l..-- 1"'""3.5" Collar 80 ~ ------- ----] - r- "1::;:.1 :; 5.5" Collar >- ¿P? 1-- .-- '- .----- ..------,- ____M__m_.n__._____..._.. '_____ - ---- --- -. - - :~-- -- i 3.5" ¡--- 1--- I - -f- -j 3 "I-s I 10.. , , ~I 10. I I I I I I I I I I I I I I I I I I I - I I I I I I I I I I I I r I ~ - ---- --,---- ---J--- ----- I I - -- -- ---- --1-- --__ ___ 1---- -_ _____ J r---r) --__ _,____ J-r-_ I . .5" Collar_ f--- r~ -__ -- --- 1---1-- -- (------- I ---- --< --- 1-- ---_ ____ ____ 120 --'- -¡--- --- ~~5.5" Collar 3.5" Joint 4 -- -- -1-1---- -'-- ---,--- --- ---. --- ,------- --- --- r- --:::È::: ---- --- ---3.5" Collar- }J 140 ¡----- --~ --- - -'-.- -'- ---- r- --'-- -- ---- r--- -- ----- -'-_._,- '--"- 3.5" Joint 5 -- ---- r- ---- þ--- t- ~ ----- t-- . ___ --- r-- --- -- j--- -.--- -- --- -.--- --- I 160 -1 -.--.-- -.- ----- -- j---- ---- ---- ~-5"Collar r- (>-.-~~13.5"collar- ì ~ ) -----~ ---- - ------ --- ----------------- -¡¿ ( L J.J 180 3.5" Joint 6 -- --- ---- ---f---- -50 o ?.oIL End of LOQ---í--- ___ Delta Metal Thickness (%) 50 Line Speed (ft/min) -200 oint 3 ,--- 1--+ I /; I; - -- r-- -1-t--- -___ ) 100 -- .¡} --- r- r-' --_ ____ 7-- r--?- --- (.__ -- -----,- ,:¡ -- I- r--- r--- -- -- -- ----1'" è-Þ ~> ¡:::::> -- i':~-" ~._.. /? -- -.------- - - --- ,--- ,- -' -- I-~ -r---- 1-- ----- ¿____ ¡-.~ - ---- "---- ~ ¡ <: ¿or -'" ------ -- j: :r , ---- -- --- '--- r- -- ___ ¡_~ .~ ! 2.4 -6.4 ---,,- --.- i-----' f- - -. 11: 1---- : ----- .[::> ::: ~> - i~:::;r,--p ¡;i.~" f ? -¡------- --'- r---'- -.--.- i I ~ ~-- --~- ---- ---r-: --- r- ¡-- f--' - ----- - '- --'- -- ,-I .1 --I---1! 1---- MTTP01 (rad) MTTP12 (rad) í t-- ---"J---- - H--- 1-- -- -- t- ___ ~ ~- ) ~ ¡:--- -- -- r---' -_ r-- __ ;t -- -----' --_ t-- r-- j--- --ï- r~~m -- -- I : -- ---~ --- - - ,-- '-i>~ ~__ r·p~r r-- --- - 'Jr---- ~-- ~, } r-- - -- -- ¡-- r-- - r-- -- -- --. --r--l~--- 1--;--- t-- ---r-- r-- . -,- ----~ ---- - ¡-.- - -- -'--- j- r-- I' r ¡¡: --- ,-- þ -- --- r--- I' -- ---- -. -- æ- 1-- --- -- ¡-.J ___ L_ __ 12.4 3.6 I I I I I I I I I I I I I I I I I r II___<~_~ 6 ~ Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: Magnetic Thickness To og (10Hz Pass) d \warrior\data \ 1 d-138\top anotation\ 1 d-138. db Kuparuk/i D-i38/run1 JPi OHZ.i 24SCAL -1 Thu Sep 28 0723:51 2006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 150 II -"-- --- ¡.--- ( I I I~~ PUPJt. :; -50 Delta Metal Thickness (%) 50 o Line Speed (ftJmin) -200 -J-I ~.. I I --f-+r--- I ) ~---I-+ -- ---- I . I--Hange -- I I I~'- I I I f-- -_ o PUpJi: 5 5" COllar -- - I .5" Collar -- 7~ ' f--- --- Loss tUi=[_-~ :- Pup Ji: ~ 3.5" Collar 1---1--- r---¡-.--- r_~r_-- 6% Metal ¡m+ LOSS-r . . r:a -._~ . '< 5" Collar ! ? 12. 1-6.< MTTP01 (rad) MTTP12 (rad) Tree Ì'--t":?- r'"-·-t~ ,~~ 1~_2 t:::. - ~ """""" ~-- ~-~ ':¡j :~ J'¡p. " J < ~F- ¿ --- &?-- J ?;; r---__r;¡; ) :> ;> è' ç" ----- --- ~ ,( I ~ , <~-: ~ <! ? ----- I-=:r - It 20 r=---. ~ ;;- <~ I~ ,; :>' :> 5 þ. d""" .: ~~ :'S, "'1 ",., -' ~ -;¡F J; ,;~ ~ '} l;wE ~' ¿¡:. :,. 2.4 MTTP01 (rad) 12.4 -6.4 MTTP12 (rad) 3.6 I I I I I I ~~ -50 Delta Metal Thickness (%) 50 0 Line Speed (ft/min) -200 12.4 3.6 I I I I I I I I I I I I I I I I I r I~ .- Magnetic Thickness To Database File: Dataset Pathname: Presentation Format Dataset Creation: Charted by: d \warríor\data \ 1 d-138\bottom anotation\ 1 d-138. db Kuparukl1 D-138/run1/P1 OHZ. 1 24SCAL -1 Thu Sep 2807:23:51 2006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1100 -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 12. -6.4 ~ PupJt 3 5" Collar r 1 - r~~_ ~-- - I----~_ ---t_-- ___ Pup Jt 6% Metall-..... ~ Loss - ~. .5" Collar --~+--- --- -1-- -::- . I ~- , - '----- Æ ¡-Ok -- 1----- ---. 1_._____ ____ ____ .__ 20 og (10Hz Pass) MTTP01 (rad) MTTP12 (rad) ~ L..... - ---.-1----- -- ---f-- ---- !~-- -_ .__ t_-- I I - :.- - - -. ~ ; '" -. :- -1-. -- -~f- - 1- .... ---t-- --.. --- - 3_5" .;¡;. 1---- --_ _ j---_ .... ~+- 5 5" ColI~r ~fl.-i"'_ 3 5:' Collar 1------ f- t---- f---+~ :~- --- ·-f 1------1--+-- -- ___ _~ 1-----4% Metal iJ.. I ( L~ss I C I I r f--- Joint 1 ~ - 1--1---- i:--- ft -'--. i J ~ I J - j---,"--- -- ~ ..~-- 1------ -~L~ __ r----!-----_ ~--- ~~ I I J I 4% Metal -fÞ.. Loss --~ 40 -+--- ,-----¡--- -~ ;... -- ~. '----- - ~ i --'- --.--- - -- ~ '- '----- ~ -:: L___ I-- -- I------ 1 ,¡.. -= 'iii~ ¡;. ¡.c --'- -- ~ --"- --- I..:' ;- ~ - -- I.. 60 3.5" . i--- ___ ____ ~ - ----- --- -+ ---- JQLOt2 2.4 -6.4 MTTP01 (r8d) MTTP12 (r8d) .--- - -- ~ i --. - --. --- j- - "'! -- ..-- if: '"---I--- - ~ ;. r -- - --- !"" """"""' - - - - ...; ~ ,.,... - - 12.4 3.6 12.4 3.6 ::::- - J rr--- ~ -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 I I I I I I I I I I r LINER (5790-6532, 00:3.500, Wt:9.30) PLUG (5898-5899, 00:3.500) Pert (5944-5983) Pert (6018-6064) I Well T e: INJ Orig 4/29/2000 Com letion: Last W/O: I KRU 1 D-138 , ROOUCTION (0-5790, 00:5.500, Wt:15.50) Gas lift Indrel/Dummy Valve 1 (5761-5762, 00:4.725) Rev Reason: PULL PLUG, set WRP Last U ate: 7/25/2005 NO 110 3560 4189 Wt 62.58 15.50 9.30 Grade H-40 L-80 l-80 Thread WELDED BTCM EUE NIP (5782-5783, 00:4.000) Vlv Cmnt CAMCO os NIPPLE BAKER GBH-22 SEAL ASSY WRP set 7/24/2005 10 2.813 3.000 0.000 SEAL (5788-5789, 00:4.000) L.twa: \""onocot"mlllps r..Xl.:ClVClLlUIl OC I\J;;µClll rIUJC;l;LJ "~ .--- Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 . . - . - ~o:Lou Grimaldi <lou_grimaldi@admin.state.ak.us>, John Spaulding. :<johI1_spaulding@admin.state.alc.us>, John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones i<jefFjones@admin.state.ak.us>, Chuck Scheve <chuck_scheve@admin.state.ak.us>, Jim Regg <jirn.~regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom \ \)-\~ ~ dOCJ-G\-.l <6:- -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us Ns"ï¿-weTf'-integrity Proj <N1878@conocophillips. com> , aogcc prudhoe bay@admin.state.ak.us Subject: Date: From: To: CC: 5c-~t4N~ Jufti ~ "1 ZOG6 Tom: I donlt remember how much of our plans we have shared with you on excavating and repairing wells at IC & 1D pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lCand 1D Casing Repair List AOGCC.xls» «SPE-100432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 __ _ __ unm __n_ __________.__u_ u.. · Content-Type: applicationlvnd.ms-excel IC and ID Casing Repair List AOGCC.xls "Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: applicationlmsword 10f2 6/26/20067:51 AM ) PRIORITY . ~ ,..._._..__,____ _'_._n'___~ ..,_._ 1 2 3 4 5 6 7 8 9 10 dCJa-O\-\.15- _ ~ 11 --, 12 13 14 15 16 ) ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates NAME TYPE -.' ..,~.. .--.-----." '"-'-.--.-.-'--'._~.'-. ,"-".--- - -.--.,-------..---..-.---- 1C-121 INJ _...__.._____ __..____ _-0 _.._._.___.__._. .___,,_ .~, .___.._.'_ ... 1C-131 INJ 10-109 INJ 10-111 INJ -I 10-120 i INJ ·-~----~--'te=~t::Z1-··--·~-·-·--··--l Gas Lift . . . . .. . I .~=~~;=;~ 1 0-132 I 1 D-136 1D-137 1 0-138 10-139 1 C-119 I . r·--------·- ·..--c·-'·-·-,··--·----..-··è·-.·····-I I·· . tG~1~f5 ...... ...' ··I····~-·-·_·~-,··-·_--t~·-;·~:·_--·..,··-···-~-,··~···~'1 l' t>~135 . .. ! .::-.'.. ···-..·:~·7;D:1·~~-··...·,·~··_-·~::_: [ Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump -- '-'--, -- --- ESP Gas Lift PTD# LEAK DEPTH (ft) - _. ---~--- ----"--,-_.~-~.-._~-_..__._--,_._.,._,--_._-- ----~..__..-.__...,_.",_._- 201-080 4 --....-- ---,~--_.__.,...._._,._- 201-185 197 -235 - --...----....-..-.. 198-166 197-221 197-181 198-109 198-121 COMMENTS I STATUS ---,...-.----...---,--..- ......- 7 5* 5* 7 None Proactive dig Proactive dig None -"--.----.----.,-.---..--- - - -----...-.------. .---. 5 200-046 200-047 200-048 200-049 - - - ------....-.- 201-139 201-220 197-184 200-112 None None Proactive dig _. "'____,__._. '-_0--'-"-' ____.".__ Proactive dig ---,"- -" .-".-.,."."..--- 8 I- I None Proactive dig 16 None None None Proactive dig Proactive dig, backup candidate (has 5001 casing) --. --.. Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 10-141 are backup options in case excavations can not be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 I,"{ù ~,r ri;\ :-l'r ,~I r \ '>. I '/", \ " .. '\ '~,I ·1' H I ': ,; '::::J ..." \ 'ì :i i ~;:',i; .:1 'i: ',\ -J) ',II Î 1\\I:j ,,-~.. ,....:;...,/ .""" J.>i ,._j.'.=J .:-....J , I~n: >') .~I ¡r-::J I :,! I 'j : : Ij 1, : ;= 'j · :il !j \,.~.) U 171:"':1 ï:"'\,~ r j'ï! ..~ j j), \ I:! ; :1'\~'\¡, \ 10J ',~ !,l/ 1,;\ \\ 11 q'l ji \ ~ ....,\, j -~ì j II ',1 'I W ", : ,. 1 ~ ",,, \ : ¡.~, L ì i;-.,:~ ,~ )1 jj ¡: ' 1\ i ,\ !.J :\J ~ J~.J ;'2; U '\.,à ;F:u FRANK H. MURKOWSK', GOVERNOR AI,ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 a60-0Lt~ Brad Gatham Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: KRU-West Sak 1D-138 Sundry Number: 305-226 . -.' '-, '\ ") Cì 2 Ol'"¡:" SCAN~\!EL lXUCl f.", ~;., ,- !~) Dear Mr. Gatham: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision Superior Court unless rehearing has been requested. DATED this¡J. day of August, 2005 Encl. Abandon -" Cf4 rJ -f) ~oS Ý STATE OF ALASKA p?j 7'//0RECEIVEDU: ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 1 2 5 l/h APPLICATION FOR SUNDRY APPROVAL 1 00 20 AAC 25,280 Alaska Oil & Gas Cons. CotmniS,I{1f; Operation Shutdown D Perforate D wai1mchotijJa Annular Disp, D Plug Perforations D Stimulate D Time Extension D Other D Perforate New Pool D Repair well Suspend D o D Re-enter Suspended Well D 1, Type of Request: D D D Pull Tubing Alter casing Change approved program 2, Operator Name: ConocoPhillips Alaska, Inc. 3, Address: p, 0, Box 100360 7, KB Elevation (ft): RKB 101' 4, Current Well Class: Development D Stratigraphic D Exploratory D Service 0 5, Permit to Drill~er: 200-048 6. API Number: 8. Property Designation: Kuparuk River Unit 50-029-22957-00 9, Well Name and Number: 1 D-138 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 'v 11, PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6543' 4199' Casing Length CONDUCTOR 110' PRODUCTION 5689' LINER 742' Size MD TVD Burst Collapse 16" 110' 5-1/2" 5790' 3-1/2" 6532' Perforation Depth MD (ft): 5944-5983, 6018-6064 Packers and SSSV Type: Baker GBH-22 no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman Jy4'P Perforation Depth TVD (ft): 3674-3704, 3731-3768 Tubing Size: 3-1/2" Tubing Grade: L-80 Tubing MD (ft): 5795' 08-30-05 Date: Packers and SSSV MD (ft) 5788 no SSSV 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D Service [] Plugged D WINJ 0 Abandoned D WDSPL D Signature RBDMS 8Fl AUG 2 2 7.005 Contact: Title: Phone 659-7224 MJ Loveland/Marie McConnell Problem Well Supervisor Date g, ¿-of Commission Use Only Conditions of approval: Notify Commission so that a representative may witness sun~~õš.. ~:t' Approved Mechanical Integrity Test .~ Location Clearance D Other ...0\\ ~ I:,,~C\o '"~ '0\' ~-\'-.)~"\t \-0 ~ \'ê... '-'::I ~ ~S\ ~~,.,,\ <J \~ \ê.~C\ '\ \" ~ ì.N:-\~\~ ~~\-a,> Cy~--~~~ C~S\"S ~~~~g~~~~ION Date: f;1fs n PIG 1 ~ 1 A GUbmit in Dupiicate / Plug Integrity D BOP Test D '--- COMMISSIONER Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE ConocoPhillips Alaska, Inc. Kuparuk WelllD-138 (PTD 2000480) RECEIVED AUG 11 Z005 Alaska Oil & Gas Cons. Commission SUNDRY NOTICE 10-403 APPROVAL REQUEST t~nchorage 08/02/05 This application for Sundry approval for Kuparuk well 1 D-I3 8 is for the repair of a surface casing leak. The well is a 5-1/2" x 3-1/2" tapered casing completion that is designated as a water only injector, completed in April of2000. On May 17, 2005, liquids in the conductor were observed while attempting to perform a State witnessed MIT-IA. The AOGCC field representative on location was Jeff Jones, notification was also sent on 5/17/05. The well was immediately plugged until diagnostics could be performed and remains secured until the casing is repaired. On 07/25/05 diagnostics were performed to locate the leak. The leak site was determined to be approximately 8' below the conductor top. With approval, repair of the surface casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3, Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top 10- feet of conductor will be removed to provide access to the surface casing. 6. CP AI Mechanical Engineers will determine appropriate patch andlor repair to return the casing to operational integrity. 7, QA/QC the repair and MIT -IA for a final integrity check. 8. Install anti-corrosion coating to repaired area of surface casing. 9. Replace the conductor and fill the void with material designed to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12, File 10-404 with the AOGCC post repair. j,,"-';', n" I \ (J'''''\ ·l ! ¡ 1-\.1 -, \...." l L ~,,','=, ,·conocoPhilUPS AlaSka,' lnc. 1 D-138 API: 500292295700 SSSV Type: NONE TUBING (0-5795, 00:3,500, 10:2.992) :>ROOUCTlON (0-5790, 00:5,500, Wt:15,50) Gas Lift ~ndrellDummy Valve 1 (5761-5762, 00:4,725) NIP (5782-5783, 00:4,000) SEAL (5788-5789, 00:4.000) LI~ ER I ~ - :'I~I. r. ~ : ~ ,:.c'. :' ~(II) \",1' ~ :'1:'1 I: LI}.: I ~ I; ~,~.~ ':' ~~ ':'c' ) ~ ':11) I I: I~ " I": ;"J J. ~ :. ,~, ) I I: ':'1' 11:(111:' .t:·I:'~ J I ~ Annular Fluid: Reference Log: Last Tag: 6082 Last Tag Date: 1/5/2002 Casing' Stri ng ~,ALL Description CONDUCTOR PRODUCTION LINER TUbing Strihg- ALL Size I Top 3.500 0 perførøtioF1s.,Surn·rnary Interval TVD 5944 - 5983 3674 - 3704 6018-6064 3731-3768 Well Type: INJ Orig 4/29/2000 Completion: LastW/O: KRU 1D-138 Angle @ TS: deg @ Angle @ TD: 21 deg @ 6543 Ref Log Date: TD: 6543 ftKB Max Hole Angle: 68 deg @ 5029 Rev Reason: PULL PLUG, set WRP Last Update: 7/25/2005 Size 16,000 5,500 3,500 Top o o 5790 Bottom 110 5790 6532 TVD 110 3560 4189 Thread WELDED BTCM EUE 8RD Wt 62.58 15,50 9,30 Grade H-40 L-80 L-80 Zone Status WSD WS C.WS B Ft SPF Date Type Comment 39 4 7/5/2000 APERF 60 Deg Ph, 31J UJ HMX 46 4 6/28/2000 IPERF 60 Deg Ph. 2.5" HSD DP VOD Latch Port TRO 1.0 INT 0.000 0 Description Date Run 4/29/2000 Vlv Cmnt Gås..,L.ift.·Måhdrels!VålVê$ St MD TVD Man Man Type V Mfr V Type Mfr 1 5761 3540 CAMCO KBG-2-9 CAMCO DMY Other:plugs, equip., etc.) - JEWELRY ¡Depth TVD Type I 5782 3554 NIP CAMCO DS NIPPLE 5788 3559 SEAL BAKER GBH-22 SEAL ASSY 5898 3639 PLUG WRP set 7/24/2005 ID 2,813 3.000 0,000 RECEIVED AUG 11 2005 Alaska Oil & Gas Con:~. Commi!::~i'm Anchor(]ge MEMORANDUM ) State of Alaska ") Alaska Oil and Gas Conservation Commission TO: Jim Regg V A~ b( z;, ~& P.I. Supervisor ~t¡ f( DATE: Thursday, May 19,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-138 KUPARUK RIV U WSAK ID-138 ~~:Ø ~·D lf~ FROM: Jeff Jones Petroleum Inspector 8rc: Inspector Reviewed By: P.I. 8uprv \~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-138 API Well Number: 50-029-22957-00-00 Insp Num: mitJJ050518082659 Permit Number: 200-048-0 Rei Insp Num: Inspector Name: Jeff Jones Inspection Date: 5/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-138 Type Inj. w TVD 3559 IA 2000 P.T. 2000480 TypeTest SPT Test psi 889.75 OA Interval 4YRTST P/F F Tubing 1500 Notes: "Monobore" type injector. When the well annulus was pressured up to 2000 PSI, the test fluid (diesel) began flowing out of the annulus cementing nipple into the cellar. The well was immediately de-pressured & shut in. I well house inspected. v :SÇJ~,NNED J\UG n 9 2005 Thursday, May 19,2005 Page I of I ') .PHILLlPS Alaska, Inc. ..... A of PHILLIPS PETROLEUM COMPANY o~~i¡r niii;P;1::sv T~;~: ~J~~~2295700 10:2.992) Annular Fluid: Reference Log' I Last Tag: 6082 ELI\' Last Tag Date: 1/5/2002 'Casing String - ALL Description CONDUCTOR PRODUCTION LINER TUþingStririg Size PRODUCTION (0-5790, OD:5,500, Wt:15,50) G as Lift landrel/Dummy Valve 1 ( 5761-5762, 00:4.725) NIP (5782-5783, OD:4,000) SEAL (578B-5789, OD:4.000) II Perf (5944-5983) LINER (5790-6532, OD:3.500. Wt:9,30) ') KRU 1 D-138 I Well Type: INJ lOng Completion: 4.'29/2000 I Last WIO: Ref Log Dale: TO:, 6543 ftKB I I\ ax Hole Anqle: 168 deg @ 5029 Size 16.000 5.500 3.500 Top o o 5790 Bottom 110 5790 6532 TVD 110 3560 4189 Wt 62.58 15.50 9.30 Grade H-40 L-BO L-80 Th read WELDED BTCM EUE 8RD 3674 - 3704 3731 - 3768 ßå~'llift:MãndrèlsNalves St MD TVD Man Man Mfr Type 1 5761 3540 CAMCO KBG-2-9 CAMCO lather (plugs. equip.. etc.) - JEWELRY I Depth TVD I Type '[ 5782 355'¡ NIP CAMCO OS NIPPLE 5738 3559 I SEAL BAKER GBH-22 SEAL ASSY V Mfr V Type V aD Latch I Port TRO DMY 1.0 INT 0.000 0 Vlv Cmnt Date Run 4/29/2000 Description ID 2.813 3.000 I, ; I t"1··~u ,~;~...K~_".., , , . -t'·- , \ \, MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc D R I I_1_1 I~ I~ SERk/Ir-Ec~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 I~VD Formation Evaluation Logs July 13, 2000 1D-138, AK-MM-00023 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, gG, Anchorage, AK 99518 11)-138: 2"x 5" _MD Resistivity & Gamma Ray Logs: 50-029-22957-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22957-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEIVED JUL 1 3 2000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company spemmy-sun ORILLI~I3 5ERVlr'E5 To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June29,2000 1D-138, AK-MM-00023 1 LDWG formatted Disc with verification listing. API#: 50-029-22957-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 6/13/00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO, 238 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor · 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1C-26 99450 MEM GR/CCL 991030 I I 1 1D-125 iJ~t~' 20248 SCMT 000529 1 1D-137 20249 SCMT 000604 1 1D-138 20250 SCMT 000604 1 , '1 · RECEIVED s,~.Eo=.- .^J~= JUN 2 ? 2000 Naska 0ii & Gas Cons. C0mmissl0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax t° (907) 561-8317. j0iillS~Fl~)u. 28-Ap'r-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-138 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 141.93' MD 6,543.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) 2_. ?_000 28-Apr-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-138PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 1,288.OO' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) Alaska Oil & Gas Cons. Commission Anchorage Permit to Drill 2000480 MD 6543 TVD DATA SUBMITTAL COMPLIANCE REPORT 9/612002 Well Name/No. KUPARUK RIV U WSAK 1D-138 Operator PHILLIPS ALASKA INC. 4200 Completion Dat 6~28~2000 .---" Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22957-00-00 REQUIRED INFORMATION Mud Log N_9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media" Fmt Name Sample N._9o Directional Survey (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Run Interval Start Stop OH I Dataset CH Received Number Comments R ~ SRVY RPT R /..R''/' SRVY RPT L /L// SCMT 5 / L ',L// DGR/EWR4-MD 2/5 L j DGR/EWR4-TVD 2/5 ~ ,,D.*,/ 9565 L ~ ~ 6 ~o¢.?~""°~.emp/P~r.,ess/Spjn ' 5 L ~ ~ l' ~,~-~ ~a.,~.~,lnjec~ on ~'rOT e 5 .............................................................. Well Cores/Samples Information: FINAL FINAL FINAL 3-5 FINAL FINAL 96 0 0 5775 110 110 5880 100 6495 6543 1288 6418 6543 4199 6080 6088 Open 7/6/2000 09565 96-6495 OH 5/2/2000 SPERRY 0-6543 OH 5/2/2000 SPERRY 0-1288 PB1 CH 6/27/2000 BL(C) 5775-6418 OH 7/1312000 110-6543 OH 7/13/2000 110-4199 OH 7/6/2000 9565 SPERRY MPT/GR/EWR4 CH 1/2/2001 5880-6080 BL, Sepia OH 6/15/2001 100-6088 BL, Sepia Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~/~ Chips Received? -'¥-FI~--' Analysis '~z-/R--- R ~.r. eiv~.d ? Daily History Received? ~.~) N Formation Tops ~)/N Comments: Permit to Drill 2000480 DATA SUBMITTAL COMPLIANCE REPORT 9/6/2002 Well Name/No. KUPARUK RIV U WSAK 1D-138 Operator PHILLIPS ALASKA INC. APl No. 50-029-22957-00-00 MD 6543 TVD 4200 Completion Dat 6/28/2000 ---~---_:~__-__~.: ..... ~__~___~:___ :__~_~_::~_~_~ .... Completion Statu 1WINJ Current Status IWINJ Date: UIC Y Compliance Reviewed By: Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1736 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 01/17~02 Well Job # Log Description Date BL Sepia CD Color 1 C-125 c~'t3 i'l~(;j PRESSURE STATION PBMS 12/28/01 I 1 1D-137 , .-~-O~.f-/ INJECTION PROFILE 01/04/02 I 1 1D-138 ~;~DE)-'OLI~, INJECTION PROFILE 01/05/02 I 1 1Q-21 /~ 5-' t~'~ .RESS-TEM. STATIONS PBMS 12/29/01 I 1 1Y-15A / c~ ~_ t ~(~ PRODUCTION PROFILE 01/02/02 I 1 1Y-15A GAS LIFT SURVEY 01/02/02 I 1 2K-28 ~0}- I~ STATIC BOTTOM HOLE PRESS SURVEY 12/16/01 I 1 3A-03A ;~O/g-I'~/ LEAK DETECTION LOG 01/08/02 I 1 30-03 /~-O~7..~ PRODUCTION PROFILE W/DEFT 12/31/01 I 1 30-03 PROD PROF FIELD DEFT PRESENTATION 12/31/01 I 1 30-03 GAS LIFT SURVEY 12/31/01 I 1 DATE: RECEIVED Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank Yli~Ja~a0il&GasC0ns.~rt 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 D Gas Fl Suspended F~ Abandoned F~ Service r~ ;-: ~ Water Injector 2. Name of Operator ~,,K,?~llf,,Cr~ 7. Permit Number Phillips Alaska, Inc. "'-'~a' ~ 200-48 3. Address i~,~!~ 8. APl Number P. O. Box 100360, Anchorage, AK 995'10:0360 ~ 50-029-22957-00 / 50-029-22957-70 ~ ........ " 9. Unit or Lease Name 4. Location of well at surface . 646' FNL, 602' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560490.7, 5959018.8) Kuparuk River Unit AtTop Producing Interval (~.., ~..~.4~/~)'~ .... *., : 10. Well Number , 1D-138 / 1D-138PB1 1432' FSL, 1951 FWL, Sec. 24, T11 N, R10E, UM (ASP: 563070.5, 5955840.8) At Total Depth :~ . 11. Field and Pool 1223' FSL, 2143' FWL, Sec. 24, T11 N, R10E, UM (ASP: 563265, 5955633.3) ' Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 30.5' feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions April 17, 2000 April 26, 2000 April 29, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 6543' MD/4200'TVD 6433' MD/ 4097' TVD YES r~ No F~I N/A feetMD 1510' ss 22. Type Electric or Other Logs Run MWD/GR/RES/PWD, CCL 23. CASING, LINER AND CEMENTING RECORD SE-i-I-lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 13.375" 68# L-80 Surface 110' 20" 7 cu yds High Early 5.5" x 15.5¢ L-80 Surface 5790' 7.875" 504 sx Class G, 379 sx Class G 3.5" 9.3# L-80 5790' 6532' 7.875" (included above) 1D-138PB1 cement plug dressed off to 145' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, Size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5795' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6018'-6064' MD 3731'-3768' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5963'-5983' MD 3688'-3704' TVD 4 spf N/A 1D-138 PB1 · 34O sx AS I & 12.2 bbls ASl 5944'-5963' MD 3674'-3688' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Water Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, appare~p~n~r~ei~ 6or water. Submit core chips. N/A ooo 0 RI G INA L Ala~a O~ & Gas Cons. Commi,~en Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak D Base West Sak D West Sak Base GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 5934' 5996' 6430' 3666' 3714' 4094' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 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. Signed' ~'"'~ ; ~ "'~'~--~ ~~--~";'~-~'--'----,---~ Title ...... F,qineeri.q~ ........ ~ Super~is~ Randy Tho~s Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 AUG 16 2000 Alaska & Gas Cons. Commi.ion Anchorage Date: 06/01/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-138 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: SPUD:04/17/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22957-00 04/16/00 (D1) TD/TVD: 110/110 SUPV:M.C. HEIM MW: 10.0 VISC: 110 PV/YP: 23/35 ( 110) COMPLETED PRE SPUD MEETING. APIWL: 6.0 Move rig from 3H pad to iD pad 18 miles. Accept rig @ 12:00 hrs. 4/16/00. N/U diverter and function test. PJSM. Pick up 3.5" Dp and stand in derrick. 04/17/00 (D2) TD/TVD: 820/817 SUPV:M.C. HEIM MW: 9.8 VISC: 200 PV/YP: 56/58 ( 710) DRLG. & SURVEYS @ 1210' APIWL: 5.0 Pre-spud meeting. Drilling from 98' to 170' Circ clean. Change out shaker screens. Drilling and surveys from 170' to 820' 04/18/00 (D3) MW: 9.8 VISC: 220 PV/YP: 64/57 APIWL: 5.0 TD/TVD: 1288/1265 ( 468) CONTINUE REPAIR AUGER, M/U BHA#2 RIH TAG CEMENT @ 102' SUPV:DONALD L. WESTER Continue directional drilling 7-7/8" hole from 820' to 1288'. Auger out. Gravel running circulate condition and mud. Conductor pipe failure, broached mud coming up around conductor and cellar box. POOH tight @ 200'. RIH with open ended DP to 130' Pump cement. 04/19/00 (D4) MW: 9.7 VISC: 210 PV/YP: 33/46 APIWL: 5.0 TD/TVD: 1288/1265 ( 0) NO LEAK YET AROUND CONDUCTOR OR CELLAR. CLEANED OUT TO SUPV:DONALD L. WESTER RIH tag cement @ 102' Stand pipe and kelly hose froze up. Thaw stand pipe and kelly hose. Clean out cement from 102' to 120'. Mud broached up around cellar box. Continue to cleanout to 140'. RIH with open ended DP to 114' R/U for cement job #2 on 13-3/8" conductor. Squeeze cement behind pipe. RIH to tag cement at 45' clean out cement to 110' 04/20/00 (D5) MW: 9.4 VISC: 230 PV/YP: 59/57 APIWL: 5.0 TD/TVD: 1396/1352 ( 108) CONTINUE DRILLING 7-7/8" TO 1920'. NOTE STILL HAVE SMA SUPV:DONALD L. WESTER Displace water with 9.7 ppg spud mud @ 110' Started to clean out cement below conductor. Contaminating mud pull back inside conductor. Pretreat mud w/bi-carb c/o slowly down to 145' Continue to clean out 7-7/8" hole from 145' to 180'. No big gravel. Appears hole closed up. POOH. RIH to 145' tag up. Clean out 7-7/8" hole from 145' to 260' Continue1396' directional drilling 7-7/8" hole ~~~ED AUG 1 6 2000 Alaska Oil & Gas Cons. Commission Anchorage Date: 06/01/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/21/00 (D6) MW: 9.5 VISC: 250 PV/YP: 57/48 APIWL: 4.5 TD/TVD: 2464/2040 (1068) CONTINUE TO WASH & REAM TO BOTTOM @ 2464' CONTINUE DRI SUPV:DONALD L. WESTER Continue directional drilling 7-7/8" hole from 1396' to 2464'. CBU. POOH 4th stand tight. Back ream up to 1600' Continue POOH tight @ 202' Work through back ream to conductor pipe @ 110' Change bit. RIH tag @ 161' work through. Tag up hard at 450' Ream and work to 818' pushing something. Continue RIH to 2200'. Washing and reaming to bottom. 04/22/00 (D7) MW: 9.4 VISC: 210 PV/YP: 44/41 APIWL: 4.2 TD/TVD: 3725/2625 (1261) SERVICE TOP DRIVE RIH TO 3725' WASH & REAM TO BOTTOM A SUPV:DONALD L. WESTER Continue directional drilling 7-7/8" hole from 2464' to 3430'. CBU and pump sweep. Short trip pull 10 stands from 3430' up to 2367' tight and swabbing. RIH Wash and ream 180' Continue drilling from 3430' to 3725' No gas off bottom. Circulate and reciprocate pump sweep. Hole appears to be clean. POOH first 11 stands. Started swabbing ream out from 2175' to 1981'. Continue to POOH no pump 110', hole in good condition above 1981' 04/23/00 (D8) MW: 9.4 VISC: 210 PV/YP: 35/40 APIWL: 4.2 TD/TVD: 4906/3129 (1181) CONTINUE DRILLING AHEAD, CHANGE OUT MUD SYSTEM TO NEW SUPV:DONALD L. WESTER RIH to 2175'. Ream to 2273', continue RIH to 2499' Ream to 2563' continue RIH to 2845', ream to 3048'. Continue RIH to 3339'. Ream to bottom @ 3725' Continue directional drilling 7-7/8" hole from 3725' to 4784'. CBU. Continue directional drilling 7-7/8" hole from 4784' to 4906' 04/24/00 (Dg) MW: 9.4 VISC: 182 PV/YP: 50/46 APIWL: 4.2 TD/TVD: 5324/3312 ( 418) CONTINUE RIH W/ BHA #5 TIGHT @ 3596' & 4638' WASH 30' SUPV:DONALD L. WESTER Continue directional drilling 7-7/8" hole from 4906' to 5265' Clean pits and load new 9.3 ppg spud mud in pits. Circulate and reciprocate and rotate while displacing old spud mud from wellbore. Continue drilling 7-7/8" hole from 5265' to 5324' Bit balled up unable to unball. Pumped sweeps of walnut & EP mud lube. POOH Pump and ream out of hole all the way. Bit balled up center jet plugged. Seal failure. RIH w/BHA #5. 04/25/00 (D10) MW: 10.0 VISC: 252 PV/YP: 50/66 APIWL: 4.0 TD/TVD: 6254/3874 ( 930) DRLG. @ 6535' (TD @ 6543') SUPV:M.C. HEIM RIH w/3.5" dp. Test MWD. RIH, tight @ 3596' and 4638' to 5189'. Wash to bottom from 5189' to 5324' Drilling and surveys from 5324' to 6254' RECEIVED AUG 16 ; 000 Alaska & Gas Cons. Commission Anchorage Date: 06/01/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/26/00 (Dll) MW: 10.0 VISC: 248 PV/YP: 50/64 TD/TVD: 6543/4200 ( 289) RUNNING 3 1/2" X 5 1/2" CSG. SUPV:M.C. HEIM APIWL: 3.8 Continue drilling and surveys from 6254' to 6311' Change out washpipe packing and service top drive. Drilling and surveys from 6311' to 6543' TD. Circ bottoms up, condition for wiper trip. Wiper trip to hwdp 8 818', while rih, tight 8 4736' to 4765' and 5286' to 6448'. Circ bottoms up, condition hole and mud for running casing. Drop survey and pump down. Monitor well, POH to run casing. 04/27/00 (D12) TD/TVD: 6543/4200 ( SUPV:M.C. HEIM MW: 9.5 VISC: 55 PV/YP: 28/16 0) NIPPLE DOWN & CLEAN DIVERTER APIWL: 3.8 PJSM. Run 3.5" & 5.5" casing. Tight spot @ 5353-5465 & 5510' Wash and work thru. Circ condition mud and hole for cementing. PJSM. Pressure test cement lines to 50009, pump pre-flush. 04/28/00 (D13) TD/TVD: 6543/4200 ( SUPV:M.C. HEIM MW: 8.5 VISC: 0) TESTING ANNULUS 0 PV/YP: 0/ 0 APIWL: 0.0 Continue pumping cement. Full returns thru out job, bump plug w/18009, check floats, OK. Pressure test casing to 30009, OK. N/D diverter. PJSM. Test BOPE to 300/3000#, OK. RIH with 3.5" tubing and jewelry. 04/29/00 (D14) TD/TVD: 6543/4200 ( SUPV:M.C. HEIM MW: 0.0 VISC: 0) RIGGED UP ON 1D-136 0 PV/YP: 0/ 0 APIWL: 0.0 Finish running 3.5" completion. Freeze protect well with diesel. Test tubing 30009, Ok. Test annulus to 30009, not holding. Test failed. RU wireline, pull dummy valve and run new dummy valve. Retest annulus 30009, OK. Set BPV. N/D BOPE. N/U tree, test to 250/50009. Secure well & prep for move. Rig release @ 2200 hrs. 4/29/2000. RECEIVED AUG 1 6 2000 Alaska Oit & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. WELL JOB SCOPE 1 D-138 DRILLING SUPPORT-CAPITAL DATE 06/28/OO DAY DALLY WORK PERF KUPARUK RIVER UNIT ELL SERVICE REPORT 2 OPERATION COMPLETE I SUCCESSFUL I KEY PERSON O Yes ~ No I O Yes ~ NoI SWS-VETROMILE mmal ~ug II-inalTbg IlnitiallA IFinallA IinitialOA IFinalOA IT~LSize oPSll 250PSll oPSll oPSll oPSll oPSll 0.000" 1D-138(4-1)) IJOB NUMBER 0602001837.4 UNIT NUMBER 2145 SUPERVISOR KENNEDY IMin ID I Depth 0.000" 0 FT DALLY SUMMARY IPERFORATE INT' (6018''6064') w/2 1/2'' Hc UJ DP' 4 sPF' 60 DEGREE PHASING' sPENT GUN sTUcK IN HOLE @2475'; E-LINE PULLED OFF. [Perf] TIME LOG ENTRY 07:30 MIRU, HAVE TO JOCKEY AROUND TO LEAVE ROOM FOR THE RIG. 08:25 TEST TOOL ON SURFACE 08:45 PT TO 3000 PSI 08:55 RIH W/CCL, 26' 2-1/2" HSD GUN 10:10 TIE IN TO SWS SCMT DATED 4-JUN-00 10:20 SHOOT AT 6038'-6064', GOOD INDICATION, POOH 11:00 RIG DOWN RUN ONE 11:20 RIH W/CCL, 20' 2-1/2" HSD GUN 12:00 TIE IN AGAIN. 12:05 SHOT, GOOD INDICATION. POOH 12:35 TOOL STUCK AT ~2450'. NOTHING IN WELL TO GET STUCK ON. TOOL WILL NOT MOVE UP OR DOWN. 12:40 ORDER PUMP. 14:00 MIRU LR. P/r TP 3500#, WAIT FOR SWS ENGINEERS TO MAKE C/O. 15:00 BRING LR ONLINE, STEP RATE UP TO 2 1/2 BPM, 1800#, PUMPING 95 DEGREE DIESEL. BEGIN WORKING LINE. 15:20 40 BBLS AWAY, NO IMPROVEMENT. STOP HEATING FLUID, BRING RATE UP TO 3.4 BPM, 2100#, CONTINUE WORKING LINE- NO CHANGE. 15:30 LR OUT OF FLUID; RDMO TO RELOAD PUMP. 17:00 LR BACK RIGGED AND PFF'D. BRING ONLINE AT 2.25 BPM, 1700# W/WARM DIESEL. RESUME WORKING LINE- NO CHANGE. 17:30 55 BBLS AWAY, STOP HEATING DIESEL, INCREASE RATE TO 3.25 BPM, 2100#. CONTINUE WORKING LINE- NO CHANGE. 17:45 80 BBLS AWAY. LR OUT OF FLUID; SHUT DOWN. DISCUSS OPTIONS. 18:00 PULL OFF GUN AT 2300#, START OOH. SPENT GUN LEFTIN HOLE AT 2475' (ELM). 18:35 OUT OF HOLE, CONFIRMED WIRE PULLED OUT OF ROPE SOCKET. 20:00 RDMO. -: .... ' RECEIVED AUG 16 2000 Alaska ~ & Gas Cons. Commission An .chorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT ELL SERVICE REPORT 1D-138(4-1)) WELL JOB SCOPE JOB NUMBER 1D-138 DRILLING SUPPORT-CAPITAL 0602001837.4 DATE DAILY WORK UNIT NUMBER 07/05/00 PERFORATE - 2.5" HSD @ 4 SPF- 31J UJ @ 60 DEGS 2145 DAY OPERATION COMPLETE SUCCESSFUL I KEY PERSON SUPERVISOR 4 ~ Yes O No ~ Yes O No ........ I ewe-SPENCER GOBER Initial Tbg I FinalTbg I Initial IA 25OPSII 0PSII oPel 0 PSI 0 PSI 0 PSI 3.500 " 2.813 " 6412 FT DAILY SUMMARY SHOT 2'GUNS · 1ST = 5963 - 5983 FT MD 2ND = 5944 - 5963 FT MD BOTH GUNS LOADED 4 SPF @ 60 DEG PHASING CHARGES -- 31J UJ HMX [Perf] TIME LOG ENTRY 14:00 CALLED DSO - SAFETY MEETING - MIRU SWS 15:00 PT WELL TO 3K PSI 15:15 RIH WITH A 20 FOOT GUN LOADED 4 SPF -31J UJ CHARGES (GUN #1) INTERVAL TO SHOOT = 5963-5983 FT MD 16:05 LOG UP TIE IN PASS ACROSS JEWELRY 16:15 LOG UP INTO POSITION TO SHOOT GUN #1 - GOOD SURFACE INDICATION - LOG OFF AND UP ACROSS JEWELRY. 17:00 AT SURFACE - CONFIRMED ALL SHOTS FIRED 17:15 GUN #2 ARMED ( INTERVAL = 5944 - 5963 FT ) - RIH 17:45 LOG DOWN ACROSS JEWELRY - GUN #2 18:00 LOGGED UP INTO POSITION TO SHOOT GUN #2 - GOOD INDICATION OF DETONATION 19:00 AT SURFACE - CONFIRMED ALL SHOTS FIRED 20:00 CALLED DSO - LEFT WELL SHUT IN - LEAVING PAD RECEIVED AUG 16 2000 Alaska 0ii & Gas Cons. Commission ~chom~e PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 11, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Revised Completion Report for 1D-138 (200-048) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the revised Completion Repo~t for the drilling operations on 1D-138. The revised report includes the perforations on this well. If you have any questions regarding this matter, please contact me at 265-6120 or Mark Chambers at 265-1319. Sincerely, Randy Thomas Kuparuk Drilling Team Leader PAI Drilling RT/skad RECEIVED AUG 1 6 2000 Alaska Oit & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-138 Surveyed: 26 April, 2000 SURVEY REPORT 28 April, 2000 Your Ref: API-500292295700 Surface Coordinates: 5959018.99 N, 560490.81 E (70° 17' 54.9650" N, 149° 30' 36.4394" W) Kelly Bushing: lO0.90ft above Mean Sea Level DRILLING SERVICES RECEIVED MAY 02 2000 Alaska 0il & Gas Cons. CommJssior, Anchorage Survey Ref: svy9185 Sperry-Sun Drilling Services Survey Report for 1D-138 Your Ref: API-500292295700 Surveyed: 26 April, 2000 North Slope Alaska Measured Depth (ft) Incl. 0.00 141.93 205.06 296.54 388.79 479.46 575.11 667.84 760.30 856.83 952.61 1049.23 1144.06 1242.69 1340.43 1437.87 1535.16 1631.77 1728.50 1825.92 1922.29 2020.16 2116.53 2213.63 2311.21 0.000 0.730 1.530 1.520 3.140 5.08O 7.590 9.390 10,080 14.250 18.780 19.270 21.090 25.150 28.860 34.440 38.400 4O.570 41.870 42.510 42.700 46.980 51.620 55.130 59.000 Azim. o.ooo 172,14o 225,340 159.020 119.430 117.430 135,630 129.420 131,79o 13o.21o 127,860 129.19o 129.300 129,670 130.900 132.21o 130.590 132.030 131.94o 133.020 133.830 137.650 138.780 138.15o 139.350 Sub-Sea Depth (ft) - 1 oo.9o 41.03 lO4,14 195.60 287.77 378.21 473.27 564.99 656.12 750.46 842.26 933.61 lO22.61 1113.30 12oo.37 1283.28 1361.56 1436.12 1508.88 1581.06 1651.99 1721.38 1784.21 1842.13 1895.17 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 141.93 205.04 296.50 388.67 479.11 574.17 665.89 757.02 851.36 943.16 1034.51 1123.51 1214.20 1301.27 1384.18 1462.46 1537.02 1609.78 1681.96 1752.89 1822.28 1885.11 1943.03 1996.07 Alaska State Plane 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100ft) (ft) 0.00 N 0.00 E 5959018,99 N 560490.81 E 0.00 0.90 S 0.12 E 5959018,10 N 560490.94 E 0,514 0.78 1.89 S 0.42 W 5959017,10 N 560490.40 E 1.963 1.21 3.88 S 0.86 W 5959015.11 N 560489.99 E 1.824 2.49 6.26 S 1.78 E 5959012.74 N 560492.64 E 2.378 6.00 9.33 S 7.51 E 5959009.72 N 560498.39 E 2.145 11.98 15.80 S 15.69 E 5959003.32 N 560506.62 E 3.330 22.14 24.98 S 25.82 E 5958994.22 N 560516.83 E 2.176 35.64 35.16 S 37.68 E 5958984.13 N 560528.77 E 0,863 51.00 48.47 S 53.05 E 5958970.95 N 560544.25 E 4.333 70.99 65.55 S 74.24 E 5958954.04 N 560565.57 E 4.780 97.57 85.17 S 98.88 E 5958934.62 N 560590.37 E 0.677 128.28 105.87 S 124.21 E 5958914.13 N 560615.87 E 1.920 160.27 130,50 S 154.09 E 5958889.74 N 560645.94 E 4,119 198.17 159.21 S 187.91 E 5958861.30 N 560680.00 E 3.838 241.73 193.14 S 226.13 E 5958827.67 N 560718.48 E 5.770 292.10 231.30 S 269.47 E 5958789.86 N 560762.13 E 4.188 348.98 271.86 S 315.60 E 5958749.67 N 560808.58 E 2.438 409.47 314.50 S 362.97 E 5958707.42 N 560856.30 E 1,345 472.36 358.69 S 411.22 E 5958663.62 N 560904.91 E 0.993 537.01 403.53 S 458.60 E 5958619.16 N 560952.64 E 0,602 601.63 452.99 S 506.67 E 5958570.10 N 561001.11 E 5,166 670.28 507.46 S 555.32 E 5958516.01 N 561050.20 E 4.896 743.21 565.78 S 607.00 E 5958458.11 N 561102.34 E 3.652 821.03 627.35 S 660.97 E 5958396.98 N 561156.81 E 4.098 902.83 RECE[VED 02 ?.000 Comment Window Point Continued... 28 April, 2000 - 9:37 -2- Alaska 0ii & G~s Cons, Cornmissior, Anchorage DriiiQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D- 138 Your Ref: AP1-$00292295700 Surveyed: 26 April, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2407.57 60,610 140.790 1943.64 2044.54 2504.73 60.970 140.840 1991.05 2091.95 2601.50 62.270 141.680 2037.05 2137.95 2697.94 62.830 141.790 2081.50 2182.40 2795.01 65.240 143.600 2124.00 2224.90 2892.88 64.850 143,610 2165.30 2266.20 2990.27 63.520 145.290 2207.71 2308.61 3086.88 63.610 144.510 2250.72 2351.62 3184.17 63.310 145.100 2294.19 - 2395.09 3281.06 64.380 145.530 2336.90 2437.80 3376.96 64.600 145.630 2378.20 2479.10 3474.04 64.070 146.830 2420.25 2521.15 3571.43 64,700 143,270 2462.36 2563.26 3669.33 65.620 142.470 2503.49 2604.39 3766,78 65,300 143.310 2543.96 2644.86 3863,93 65,560 143.100 2584.36 2685.26 3961,39 65,020 142.540 2625.10 2726.00 4057.59 65,120 142.540 2665.65 2766.55 4155.03 64,830 142.360 2706.87 2807.77 4252.40 64.440 143.190 2748.58 2849.48 4349.75 65.020 143.230 2790.13 2891.03 4446.43 65.610 142.540 2830.51 2931.41 4544.39 65.230 143.140 2871.26 2972.16 4640.76 64.460 143.360 2912.22 3013.12 4736.26 64.130 143.730 2953.64 3054.54 Local Coordinates Northings Eastings (ft) (ft) 691.22 S 714.41E 756.95 S 768.00 E 823.36 S 821.27 E 890.56 S 874.27 E 959.98 S 927.15 E 1031.40 S 979.79 E 1102.72 S 1030.77 E 1173.50 S 1080.51 E 1244.62 S 1130.68 E 1316.14 S 1180.17 E 1387.53 S 1229.09 E 1460.27 S 1277.73 E 1532.23 S 1328.03 E 1603.06 S 1381.66 E 1673.75 S 1435.14 E 1744.50 S 1488.06 E 1815.04 S 1541.57 E 1884,29 S 1594.63 E 1954,29 S 1648.44 E 2024,35 S 1701.66 E 2094.85 S 1754.38 E 2164.89 S 1807.39 E 2235.89 S 1861.20 E 2305.78 S 1913.39 E 2374.99 S 1964.52 E Global Coordinates Northings Eastings (ft) (ft) 5958333.54 N 561210.77 E 5958268.24 N 561264.87 E 5958202.26 N 561318.68 E 5958135.50 N 561372.22 E 5958066.51 N 561425.65 E 5957995.51 N 561478.88 E 5957924.60 N 561530.42 E 5957854.23 N 561580.73 E 5957783.51 N 561631.47 E 5957712.40 N 561681.53 E 5957641.40 N 561731.03 E 5957569.05 N 561780.25 E 5957497.50 N 561831.13 E 5957427.11N 561885.33 E 5957356.85 N 561939.38 E 5957286.52 N 561992.87 E 5957216.42 N 562046.94 E 5957147.60 N 562100.55 E 5957078.03 N 562154.92 E 5957008.41 N 562208.71 E 5956938.33 N 562262.00 E 5956868.71 N 562315.57 E 5956798.16 N 562369.95 E 5956728.69 N 562422.70 E 5956659.89 N 562474.39 E Dogleg Rate (°/100ft) 2,112 0.373 1.545 0,589 2.996 0.399 2.068 0.729 0.624 1.174 0.248 1.241 3.359 1.197 0.850 0.332 0.761 0.104 0,341 0.868 0.597 0.890 0.679 0.825 0.491 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 986.09 1070.89 1156.03 1241.61 1328.84 1417.50 1505.04 1591.38 1678.25 1765.01 1851.32 1938.50 2026.11 2114.92 2203.53 2291.84 2380.34 2467.56 2555.84 2643.79 2731.78 2819.59 2908.64 2995.82 3081.80 Comment 28 April, 2000 - 9:37 -3- RECEIVED Continued... ~AY 0 2-2000 DrillQuestl.05.05 Sperry-Sun Drilling Services Survey Report for 1D- 138 Your Ref: AP1-$00292295700 Surveyed: 26 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Vertical Rate Section (°/lOOff) (ft) Comment 4834.50 63.400 144.120 2997.07 3097.97 2446.21 S 2016.41 E 4931.37 65.420 144.620 3038.91 3139.81 2517.22 S 2067.30 E 5029.31 67.700 145.130 3077.87 3178.77 2590.72 S 2119.00 E 5126.25 67.650 145.300 3114.69 3215.59 2664.36 S 2170.16 E 5222.68 66.370 143.700 3152.36 3253.26 2736.63 S 2221.70 E 5318.89 67.220 144.260 3190.26 3291.16 2808.15 S 2273.70 E 5417.85 60.720 143.700 3233.67 3334.57 2880.04 S 2325.95 E 5514.06 55.790 144.990 3284.27 3385.17 2946.48 S 2373.64 E 5608.27 53.380 145.720 3338.87 3439.77 3009.64 S 2417.29 E 5706.13 48.260 145.600 3400.67 3501.57 3072.26 S 2460.07 E 5804.00 43.540 142.590 3468.77 3569.67 3129.20 S 2501.21 E 5900,73 41.610 142.850 3539.99 3640.89 3181.27 S 2540.85 E 5997.02 38.760 142.040 3613.55 3714.45 3230.53 S 2578.70 E 6093.76 34.330 137.550 3691.26 3792.16 3274.56 S 2615.77 E 6189.72 28.320 136.600 3773.20 3874.10 3311.10 S 2649.70 E 6286.40 23.360 134.690 3860.19 3961.09 3341.26 S 2679.10 E 6385.62 21.420 133.630 3951.92 4052.82 3367.60 S 2706.20 E 6478.32 21.450 134.950 4038.21 4139.11 3391.25 S 2730.45 E 6543.00 21.450 134.950 4098.41 4199.31 3407.96 S 2747.19 E 5956589.09 N 562526.85 5956518.49 N 562578.31 5956445.42 N 562630.59 5956372.18 N 562682.34 5956300.33 N 562734.46 5956229.23 N 562787.04 5956157.76 N 562839.87 5956091.71 N 562888.10 5956028.90 N 562932.25 5955966.63 N 562975.53 5955910.02 N 563017.12 5955858.28 N 563057.18 5955809.33 N 563095.43 5955765.59 N 563132.85 5955729.33 N 563167.08 5955699.41 N 563196.72 5955673.29 N 563224.03 5955649.83 N 563248.47 5955633.25 N 563265.34 E 0.824 3169.83 E 2.137 3257,07 E 2.376 3346,75 E 0.170 3436,21 E 2.024 3524,84 E 1.033 3613,17 E 6.588 3701.95 E 5.249 3783,63 E 2.635 3860.21 E 5.233 3935.82 E 5.303 4005.98 E 2.004 4071.41 E 3.009 4133.52 E 5.346 4191.06 E 6.284 4240.79 E 5.201 4282.71 E 1.997 4320.20 E 0.521 4353.82 E 0.000 4377.33 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.655° (17-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 141.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6543.00ft., The Bottom Hole Displacement is 4377.36ft., in the Direction of 141.127° (True). Continued... 28 April, 2000 - 9:37 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D- 138 Your Ref: AP1-$00292295700 Surveyed: 26 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) o.00 141.93 654:3.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 141.93 0.90 S 0.12 E 4199.31 3407.96 S 2747.19 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (.) (ft) 6543.00 4199.31 Survey Tool Description MWD Magnetic 28 April, 2000 - 9:37 - 5 - DrillQuest 1.05.05 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-138PB1 Surveyed: 18 April, 2000 SURVEY REPORT 28 April, 2000 Your Ref: API-500292295770 Surface Coordinates: 5959018.99 N, 560490.81 E (70° 17' 54.9650" N, 149° 30' 36.4394" W) Kelly Bushing: lO0.90ft above Mean Sea Level DRILLING SERVICES RECEIVED ~AY 0 2 ~00~ Alaska 0il 8, Gas Cons. Commission Anchorage Survey Ref: svy9183 Sperry-Sun Drilling Services Survey Report for 1D- 138PB 1 Your Ref: API-500292295770 Surveyed: 18 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth , Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°~OOft) Vertical Section (ft) Comment o.00 0.000 0.000 -100.90 0.00 0.00 N 0.00 E 141.93 0.730 172.14o 41.03 141.93 0.90 S 0.12 E 209.14 1.720 195.530 108.22 209.12 2.29 S 0.09 W 298.09 2.410 160.380 197.12 298.02 5.34 S 0.18 E 390.88 3.250 145.040 289.79 390.69 9.33 S 2.34 E 482.13 3.420 150.080 380.89 481.79 13.81 S 5.18 E 574.66 4.560 131.300 473.20 574.10 18.63 S 9.32 E 666.63 7.420 130.270 564.65 665.55 24.88 S 16.60 E 758.77 8.100 130.980 655.95 756.85 32.99 S 26.04 E 856.37 12.730 129.720 751.92 852.82 44.37 S 39.51 E 952.59 15.130 131.300 845.30 946.20 59.44 S 57.10 E 1048.83 14.720 131.120 938.29 1039.19 75.77 S 75.75 E 1145.62 16.820 130.630 1031.43 1132.33 92.98 S 95.65 E 1288.00 16.820 130.630 1167.72 1268.62 119.81 $ 126.91 E 5959018.99 N 560490.81 E 0.00 5959018.10 N 560490.94 E 0.514 0.78 5959016.70 N 560490.74 E 1.621 1.73 5959013.65 N 560491.04 E 1.585 4.28 5959009.68 N 560493.23 E 1.211 8.75 5959005.22 N 560496.11 E 0.371 14.02 5959000.43 N 560500.28 E 1.859 20.37 5958994.24 N 560507.61 E 3.112 29.80 5958986.21 N 560517.12 E 0.745 42.03 5958974.93 N 560530.68 E 4.749 59.34 5958960.01 N 560548.39 E 2.525 82.09 5958943.83 N 560567.17 E 0.429 106.49 5958926.78 N 560587.20 E 2.174 132.36 5958900.21N 560618.68 E 0.000 172.84 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Sudace is 26.655° (17-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 141.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1288.00ft., The Bottom Hole Displacement is 174.53ft., in the Direction of 133.350° (True). RECEIVED ~/IAY 0 2 ~000 Alaska Oil & Gas Cons. CommJssJor Anchorage Continued... 28 April, 2000 - 8:42 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D-138PB1 Your Ref: API-500292295770 Surveyed: 18 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 1288.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 1268.62 119.81 S 126.91 E Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 1288.00 1268.62 Survey Tool Description MWD Magnetic RECEIVED MAY 0 2 200~ Alaska Oil & Gas'C~issi°n 28 April, 2000 - 8:42 - 3 - Ai~C~i0i'a[~l~ DrillQuest 1.05.05 [Fwd: Broaching 13 3/8" Conductor 1D-138] __ Subject: [Fwd: Broaching 13 3/8" Conductor 1D-138] Date: Thu, 20 Apr 2000 13:54:42 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: aogcc north slope address <aogcc_prudhoe bay~admin.state.ak.us> Subject: Date: From: Organization: To: CC: Re: Broaching 13 3/8" Conductor 1D-138 Wed, 19 Apr 2000 08:26:13 -0800 John Spaulding <john_spaulding~admin.state.ak.us> State of Alaska, Dept ofAdmin, AOGCC Nordic 3 Company Man <N1433~mail.aai.arco.com> blair_wondzell~admin.state.ak.us, tom_maunder~admin.state.ak.us, aogcc_prudhoe bay~admin.state.ak.us Don, Thanks for the information. In our conversation last night, you mentioned that the differences between this conductor and others are that the size has been reduced (13-3/8" versus 16") and that the contractor said these conductor holes were wet. Good luck as you proceed ahead. Please keep us informed of and further difficulties. Tom Maunder Nordic 3 Company Man wrote: While drilling 7-7/8" hole at 1288'. Gravel started running circulated and conditoned hole and mud. Mud broached up around 13-3/8" conductor & cellar box. POOH , 13-3/8" conductor shoe ~ 110' RT Nordic rig #3. RIH w~ opened drill pipe to 130' displaced mud w~ water. Closed bag w~ knive valve closed circulated & displaced mud from around conductor. Spored end of drill pipe ~ 100. Dowell mixed and pumped 340 sks ARCTICSET 1 Cement ~ 15. 7 ppg slurry (54 bbl 's) Had full returns through out job. No cement to surface but cement colored water. CIP ~ 1700 hfs 4/18/00 Company Man Donald L. Wester 1 of 1 4/26/00 9:57 AM Re: Broaching 13 3/8" Conductor 1D-138 _. Subject: Re: Broaching 13 3/8" Conductor 1D-138 Date: Wed, 19 Apr 2000 08:26:13 -0800 From: John Spaulding <john_spaulding~admin.state.ak.us> ~n~erna~ Organization: State of Alaska, Dept of Admin, AOGCC To: Nordic 3 Company Man <N 1433~mail.aai.arco.com> CC: blair_wondzell~admin.state.ak.us, tom maunder~admin.state.ak.us, aogcc_prudhoe_bay~admin.state.ak.us Don, Thanks for the information. In our conversation last night, you mentioned that the differences between this conductor and others are that the size has been reduced (13-3/8" versus 16") and that the contractor said these conductor holes were wet. Good luck as you proceed ahead. Please keep us informed of and further difficulties. Tom Maunder Nordic 3 Company Man wrote: > While drilling 7-7/8" hole at 1288' Gravel started running circulated and > conditoned hole and mud. Mud broached up around 13-3/8" conductor & cellar box. > POOH , 13-3/8" conductor shoe ~ 110' RT Nordic rig #3. RIH w~ opened drill pipe > to 130' displaced mud w~ water. Closed bag w~ knive valve closed circulated & > displaced mud from around conductor. Spored end of drill pipe ~ 100. Dowell > mixed and pumped 340 sks ARCTICSET 1 Cement ~ 15. 7 ppg slurry (54 bbl 's) Had > full returns through out job. No cement to surface but cement colored water. CIP > ~ 1700 hrs 4/18/00 > Company Man > Donald L. Wester 1 ofl 4/19/00 10:14 AM MEMORANDUM TO' State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson'~ DATE: April 17, 2000 Chairman THRU' Blair Wondzeli, P. I. Supervisor FILE NO: Dvtrinsp. Nordic 3.DOC FROM' Tom Maunder, Petroleum Engineer SUBJECT: Diverter Inspection AAI KRU 1 D-138 3----~.-___ .. 200-048 ~ April 16, 2000' I traveled to Nordic 3 to witness the Diverter function test on well 1D-138 in the Kuparuk River Field for Arco Alaska Inc. The AOGCC test report is attached for reference. All equipment was in place when I arrived. Due to the planned 7-7/8" surface hole size, the diverter was 13-5/8". The controls were actuated and the diverter valve opened as the bag closed. In addition to the function test, an accumulator test was performed. 200 psi recovery was accomplished in 13 seconds with full charge achieved in 1 minute 18 seconds. I also reviewed the calibration and testing records for the H2S and methane gas detectors. All were up-to-date and in order. SUMMARY: I witnessed the successful Diverter function test on Nordic 3 and reviewed the calibration and testing records of the H2S and methane gas detectors in KRU on well 1-138 for AAI. No failures witnessed. Test time 1 hours. Attachments: Diverter Nordic 3 1D-138 4-16-2000TM cc; NON-CONFIDENTIAL Dvtrinsp Nordic 3 4-16-2000 Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA OIL AND GAS CONSERVATION COM, Diverter Systems Inspection Report Nordic Arco 1 D-138 23 T. 11N R. Operation: Development Rig No. 3 PTD # Oper. Rep.: Rig Rep.: 10E Merdian Umiat ,SION Date: X Exploratory: 200-048 Rig Ph. # MC Helm 4/1 8/O0 659-7872 Shane McGheehan TEST DATA:::: MISC. INSPECTIONS: Location Gen.: P Housekeeping: P Reserve Pit: N/A (Gen.) Well Sign: P Drlg. Rig: P Flare Pit: N/A DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 1 6 Vent Line(s) Length: 11 0 Line(s) Bifurcated: N/A Line(s) Down Wind: Yes Line(s) Anchored: Yes Turns Targeted / Long Radius: N/A 13-5/8 in. in, ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: 285O 2250 min. 18 min. 78 Four @ 1 900 MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Light Alarm NA NA Yes Yes NA NA Light Alarm P P P P GAS DETECTORS: Methane Hydrogen Sulfide: psig psig sec. sec, psig : :: : : DIVERTER scHEMATIc H2S and methane gas detector calibrations reviewed. All up to date. North Non Compliance Items Remarks: 0 Repair Items Within N/A Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c - Database c - Trip Rpt File c - Inspector AOGCC REP.: TOm Maunder OPERATOR REP.: Diverter Nordic 3 1D-138 4-16-2000 TM.xls MC Helm DVTRINSP.XLT (REV. 1/94) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage.. AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 1 D- 138 ARCO Alaska. Inc. Permit No: 200-048 Sur. Loc. 648'FNL, 598'FEL, See. 23, T1 IN, R10E: UM Btmhole Loc. 1245'FSL. 2110:FWL, See. 24. T1 IN, R10E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No ID-138 Please note that any disposal of fluids generated from this drilling operation which are pumped down thc surface/production casing annulus of a well approved for annular disposal on Drill Site ID must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and thc mechanical integrit).' (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed bcfore drilling bclow the surface casing shoe, must be given so that a rcprcsentative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~Sinc / Robert N. Christenson, P.E. Chair BY ORDER OF T~I~COMMISSION DATED this lCD~''~-- day of April, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ofwork: Drill ~' Redrill D I ih. Type ofweil. Exploratory BI StratigraphicTest BI Development Oil E~] Re-entry F~ Deepen F~I Service D Development Gas BI Single Zone ~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 101' above sea level 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 648' FNL, 598' FEL, Sec. 23, T11N, R10E, UM (ASP: 560493.4, 5959019) Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1376' FSL, 2009' FWL, Sec. 24, T11N, R10E, UM (ASP: 563129, 5955786) 1 D-138 #U-630610 At total depth 9. Approximate spud date Amount 1245' FSL, 2110' FWL, Sec. 24. T11N, R10E, UM (ASP: 563231.5, 5955655.6) April 24, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1245' @ TD feetI 1D-08 44.6 @ 386' MD feet 2560 6528 ' MD / 4188 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300' MD Maximum hole angle 65° Maximum surface 1396 psig At total depth (TVD) 1834 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 13.375" 68# L-80 BTC 50' 30' 30' 80' 80' Pre-installed 7.875" 5.5"x 15.5# L-80 BTCM 5792' 30' 30' 5822' 3579' 520 sx Class G & 400 sx Class G 7.875" 3.5" 9.3# L-80 EUE 8rd M 706' 5822' 3579' 6528' 4188' (included in above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production #REF! ': ' '':'~ ': Perforation depth: measured ,, ' true vertical ' '.i.: i~-i'. ~",~ !i~;:-!,: i)!'i~ ,~\ ~; ',': ', i0 [' ¢:.:-.!, 20. Attachments Filing fee [~] Property Plat D BOP Sketch D Diverter Sketch [] Drilling program Drilling fluid program ~] Time vs depth plot DReffaction analysis D Seabed report D 20 AAC 25.050 requirements D 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Chambers 265-131~. Signed ~ ~'. ~~ Title: DrillblgEngineoringSuporvi, o¢' Date Chip Alvord PreD~r~,d bv ,~har~n AIl.~ur~-Dr~k~ Commission Use Onl} / Permit Number APl number Approval date.// / See cover letter ,~4:20 -" '~"~ 50- ~ .~. ¢" 2- ~.- ? ~ ~'?// 0/(~)0 for other requirements Conditions of approval Samples required FI Yes [~ No Mud Icg required E~] Yes ~ No Hydrogen sulfldemeasures D Yes J~] No Directional surveyrequired J~ Yes E] No Required working pressure for BOPE D2M; D (~)D 5M; D l OM; D E~ ~.~)(. 4 (rv~ (' ''~ Other: Approved by Robert N. (~hri.~t~r~e~,~ Commissioner the commission Date 0 Form 10-401 Rev. 12/1/85 · Submit in triplicate 1 D-138 West Sak IVlonobore Injector 5-1/2" x 3~1/2" Tapered String Planned Completion 13-3/8" 68# L-80 BTC ~ Conductor @ 80' TAM 5~1/2'' Port Collar ~ BTC Box x Pin set @ +/- 1000' TVD Production csg, 5-1/2" 15.5# L-80 LTCM or BTCM XO / SBE to sun'ace Set XO / SBE +/- 100' above D Sands (plan to pedorate elf ug) 3-1/2" 9.3# L-80 EUE 8RD-Mod TD to XO/SBE 3-1/2" Vetco-Gray Tubing Hanger w/ 3-1/2" EUE 8RD-Mod pin down. 3-f/2" 9.3# L-80 EUE 8RD Mod Tubing to surface, 3-1/2" x 1" Camco 'KBG~2~9! GLM w/DV & latch, 3-1/2" x 6' Nandling Pups installed on top and bo0om w/BTCM Pin x EUE 8RD Mod Box Special Clearance CoupliBgs. 1 Joint 3~1Z2~I 9,3# Lr80 EUE 8RD-Mod Tubing. 3-1/2" Camco iDS' Landing Nipple w/2.812" No-Go Profile, 1 Joint 3~1/2'~ 9,3# L-80 EUE 8RD*Mod Tubing. 3-1/2' Baker GBH-22 '80-40' Locater Seal Assembly w/12' of Seals and Locato,r 3-1/2" x 6' L-80 Handling Pup installed on top. EUE 8RD-Mod Box up, Baker Casing Bore Recepticle Assembly Baker 5-1/2" XO / Handling Pup BTC x LTC Baker XO Coupling w/locater shoulder LTC x SBE Baker 5" OD x 4 D Seal Bore Extension 12' aker XO. SBE x 3-1/2" EUE 8RD 3-1/2 B.3# L-80 BUE 8RD Mod Tubing from Lana~ng Sleeve to SBE. 3q/2" ~Veatherford [.ending Sleeve instal~e~ in tod of joint #3. Joints 3~1/2" 9.3¢ L-80 BUE 8RD-Mod Tubing. 3-1/2'' Weatherford Float Col~ar w/3-1/2 EUE 8rd Box x Pin Joints 3-I/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2'' Weatnerford Float Shoe w/3-1 2" EUE 8~d Box Up. TO @ 6528 MD/4188'T D '~AC 03/15/00 Drill, Case and Completion Plan for West Sak 1 D-138 Monobore Iniector General Procedure: 1. Excavate cellar, install cellar box, set and cement 13-3/8". Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 7-7/8" hole to desired target through West Sak interval. Run MWD / /WD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 3-1/2" 9.3# L-80 EUE 8rd x 5-1/2" 15.5# L-80 BTCM tapered casing string to surface. Displace cement with mud and perform stage job or top iob if required. Note: 5-1/2" Port Collar to be installed @ +/- 1,000' TVD. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. 7. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 8. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to brine. 9. Sting into seal bore extension and space out. 10. With seal assembly unstung, freeze protect well with diesel 11. Sting into seal bore extension and land tubing. 12. Using diesel, pressure test tubing and annulus to 3,000 psi. Install back pressure valve. 13. Nipple down BOP stack. Install production tree and pressure test same. 14. Secure well and release rig. 15. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 16. Rig up E-line unit and RIH with CBL / CET. Run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 17. Rig up E-line unit and RIH with through-tubing perforating guns. 18. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 19. Install back pressure valve, shut in and secure well. MAC 3/28/00 Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1 D-138 Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Drilling Fluid Properties Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5 8-15 30-60 250 15-30 25-55 8-15 8-9 5-8 Spud to TD Final 9.4 - 9.6* 11-22 30-60 250 10-25 25-55 6 8-9 5-8 Drilling Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators * 9.8 ppg if hydrates are encountered. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000 feet TVD. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1 D-138 well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from sudace through the West Sak pay zone can be safely drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.3 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,653'. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3988 ft)(0.46 - 0.11 psi/ft) = 1396 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of 3,000 psi. The 5-1/2" 15.5# L-80 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-138 area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1 D drilling results, 9.8 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1 D-138. Well Proximity Risks: The nearest existing well to 1 D-138 is 1 D-08. The wells are 44.6' from each other at a depth of 386' MD. The nearest planned well to 1 D-138 is 1 D-139. As currently planned, the wells will be 13.4' from each other at a depth of 500' MD. Gyro Surveys will be required to validate survey integrity. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1 D-138 surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 16" DIVE-'TER SCHEMATIC- Nc- dic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 1 o" 15o ANSI Blanked 3 B~IIkV lye Open ~ - · To Accumulator I Closed r ~ --~ ~_ .... From Accumulator , Open . Maintenance & Operation Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16"x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line - Nordic MAC 3/7/OO I" 5000 psi BOP Stac Kuparuk River Unit West Sak Operations -Injector Wells J L 4 3 2 I Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form, Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" x 11" 5000 psi Double Studded Adapter/Spacer Spool 4. 11" 5000 psi Pipe Rams 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines 6. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 7. 11" 5000 psi Annular Preventer MAC 3/28/00 1D-138 West Sak Injector Well Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 300 % above. Drilled with 7 7/8" bit. 5 V2", 15.5# X 31/z", 9.3# Tapered string. Crossover Joint @ 5808'(approximately 100' above the D Sands), TD @ 6528' MD. Top of Tail cement @ 5200' (minimum of 500' above the top of the crossover joint). Single Stage Design. Port Collar contingency at 1000' MD if no cement to surface. Base of the Permafrost at 1762' MD, Volume Calcs: Pump 20 bbls Arco Preflush, 50 bbls MUDPUSH XL @ 10.0 ppg. Cement from MD to 5200' with Class G + adds @15.8 ppg and from 5200' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft3/sk Above Permafrost: 5.5" x OH Below Permafrost: 5.5" x OH Total: 1220.7 ft3 + 1016.1 ft3 = 2236.8 ft3/4.44 ft3/sk - (300% excess): (1762') x 0.1732 ft3/ft x 4 = (45% excess): (5808'-1762') x 0.1732 ft3/ft x 1.45 - 1220.7 ft3 1016.1 ft3 2236.8 ft3 504 sks - Round up to 520 sks Have an additional 260 sks of lead on location for Top Ouff2'~° stage, if necessary - enough cement to f'fll the annular space (300% excess) and the inside of the drill pipe from port collar to surface. Tail Slurry Requirements: 15.8 ppg Class G + 0.5%S1, 0.2%D46, 0.3%D65, 0.4%D167 - 1.17 ft3/sk Below Permafrost: 5.5" x OH (45% Excess): (5808'-5200') x 0.1732 ft3/ft x 1.45 = 3.5" x OH (45% Excess): (6528'-5808') x 0.2714 ft3/ft x 1.45 = 80' shoe joint: 80' x 0.04822 ft3/ft = Total: 152.7 ft3 283.3 ft3 3.9 ft3 152.7 ft3 + 283.3 ft3 + 3.9 = 440.0 ft3/1.17 ft3/sk = 440.0 ft3 376 sks - Round up to 400 sks BHST = 70F, BHCT = 65F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.2 ppg MUDPUSH XL, 504 sks (399 bbls) ASLite Lead, drop plug, 379 sks (79 bbls) Class G + adds Tail, drop plug, displace with rig. Circulation: Circulation at or less than 7 bpm is within safe ECD limits without breaking down the formation. Perform the designed cement job at a rate between 4 and 6 BPM for mud removal in Effective Laminar Flow. Drop the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 1300 psi at 3 bpm. At 7 bpm, expect 10 minutes of u-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 9.5 ppg or lower, Pv =15 to 20, Ty = 15 to 20 or lower - As thin and as light as possible to aid in the removal of mud during the cement job. This is the most important part of the cement job. James Franks can be reached at the Arco Tower, home or by cellular at the following numbers regarding this job or any other assistance: 265-6205(w), 248-3595(h), 223-5148(ce11). Jdf 3/24/00 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-13E WPs 0- oo'~0~Start. Dir @ 1.500°/100ft: 300.00ft MD, 300.00ft TVD I DrillQuest Proposal Data for 1D-138 WP1 Vertical O~jin: 1D-138 Hodzo~taJ O~gil: ~tD-138 DorJeg severity: Degrees per 10oft Veil/col Sec'f~m Azimuth: 141.313' Ve rlx~ Sectk)n Description: 1D-13& Verlk~l Sec~,~ Orkj~n: 0.0O N.O.00 E MeasuredIncl. AzJm. Vertical Northlngs Ea~nGs VerUcal D<x]l ecj Depth Depth Section Rate 600 -- 0.00 0.0000.461 0.00 o.¢Jo N oooE 0.00 300.000.0o00.461 30o.00 00ON o.ooE om 000o 500.003.00o130.000499.91 3.36s 4.01 E 5.13 1.500 780.0010.0oo 130.0oo777.94 ~3.73 S 2828 E 36.19 2.5[0 1675.47 41.342 130.o001575.00 269.98>; 321.75 E411.85 3.5OO 18~.4741.342 130.OO~1687.62 333.67 .q397.65 E50').010.000 2475.27 64.997 143.7342075.54 715.60S 742 16 E1022.474.0OO 5276.35 64.997 143.7343259.45 2762.41 S2243.82 I-5 3558.80O.OOO 6107.73 31.750 14Z733 3804.6O 3~q4.12 S260'9.45 E 4171.154.6¢Jo 6315.53 ~.44114~260 3988.0O 3330.45 $ 2667.96 E 4267.304.000 6527.50 14.965 141.5184188.O0 3385.32 S2710.87 E 4336.964.800 1200 - 800 - 2400 -- '- 3000 - 3500 - F ir Rate Increase @ 2.500°/100ft: 500.0Oft MD, 499.91ft TVD Current Wall Properties ' Well: 1D- 138 WPs o0.0o Ho~zonta] Cootd~ates: . Rel. C4obal Coondhate~: 5959o1901 N. 5r~3493.44 E Fief. Well: 885.23 S. 2.18 E ir Rate Increase @ 3.500°/100ft: 780.00ft MD, 777.94ft TVD mr. eeog,~p~c~,~m:70' ~r 54 965o' N. to'ao'~.a627'w 95.0oft at. Ce Wel .00 North Rc4em,-,ce: Tr,.,e Ner~h Units: Feel 1080.00 10O.00 1400.00 1500.0O nd Dir: 1675.47lt MD, 1575.00ft TVD 70o.0o "~0oStart Dir @ 4.000°/100It: 1825.47ft MD, 1687.62ft TVD .~p/End D~r': 2475.27ft MD, 2075.54ft TVD 700.0o ,...%.% 0o I I I I I I 0 600 1200 1800 2400 3000 Scale: 1 inch = 600ft Vertical Section Section Azimuth: 141.313° (True North) .~i; 4.000°/100ft: 5276.35ft MD, 3259.45ft TVD ................... · 0o ................................... D - $653.00 TVD ................................ ............. ~~'b~:/" 3804. O0 TVD 3254.12 S, 2609.45 E V'0o .................................. ......................... ,_,988.00 ~ ~-~.__'~ota, Oe.,.: ~.50. ~O, 4188.00. TV° 5 1/2' X 3 1/2' Liner - 6527.50 MD, 4188.00 TVD I 4000 4500 OO :E:o II ~' -~ 4000 - .-- -- Scale: 1 inch = 500ft Vertical Section Section Azimuth: 141.313° (True North) Sl:3er~r~,-sun ~'-'~ i~ L.i N G SG~VtC:ES I DrillQuest" North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1 D-138 WPs 0 -- -500 - -1000 - -1500 - ,-- o Z -2000 -- -2500 - ~_ -3000 - O O I1 ._ ,r-- -~ -3500 - Propossl Data for 1D-138 WP1 VedJcal Origin: 1D-138 Hodz~ntal O~Jh: lb- 13~ Measurement Ur~ts: ft Vertkal Soc~on Az~mu~l: 141.313~ Ve r'd<;al Sec~o~ Dosed p ~on: 1D-138 Vet1~al Sec~Jon Origin: O.00 N,0.0O E Mea~lredIncl. gzJm. Ve~cal Northing$ Eastthg s VeStalDogl~:J Depth Depth Se~UonRate 0.00 0.0000.461 0.00 o.co N O.DO E 0.00 300.00O.O/X) 0.461 300.00 0.00 .~ 0 CO Ii0.00 500.003.0O0130.000499.91 3.365 401 E 5.13 1500 780.00IO. OC~ 130. O0O 777.94 23.73 .q 28.28 E36.19 1675.47 41.342 130.0/X) 1575.00 269.98 S 321.75 E 411.g53.5{)3 1825.47 41.342 130.0001687.62 333.67 S 397.65 E 5(7).01 0.0oo 2475.27 64.997 143.7342075.54 715.605 742.16 E 1022474.O0O 5276.35 64.997 143.7343259.45 276~41 S 2243.82 E 3558.80 6107.73 31.750 142733 3804.00 3~q4.12 $ 2600 45 E 4171.15 4.0C~ 6315.53 3.441142.2603998.00 3330.45 S26~7.96 E 4267.30 6527.50 14.965 141.5184185.00 3395.32 S2710.87 E 4336.96 Scale: 1 inch = 500ft Eastings 0 500 1000 1500 2000 2500 Current Well Properties __ ~ Start Dir @ 1.500°/100ft: 300.00ft MD, 300.00ft TVD ~ Dir Rate Increase @ 2 500°/100ft ' 500 00ft MD 499 91ft TVD IHo~zo.~ C~.~: ~ ' ' ' ' ' I Roi. Glo~al Coominate.s: $.9~9~19.01 N. 5~3493.44 E '~.- -"~ I Rof. Wea: 1~85.23 S, 2.18 E "~5o.0o ~ Dir Rate Increase @ 3.500°/100ft: 780.00ft MD, 777.94ft TVD I P,~.Ge~Jmph/calC,<mrdinale~: 70' IT54.9~50' N. 149'30'363627'W . ~ End Dir: 1675.47ft MD, 1575.00R TVD I Start Dir @ 4.000°/100ft: 1825.47ft MD, 1687.62ft TVD u~.s: ~.1 750.00 ~950.0O 10O.0O E 30o.0o 40o.0o 45o.oo - o.0o ~,7oo.0o 75o.0o 80o.0o 85o.0o 0o o.0o o.0o 50.00 1 oo.0o 15000 30o0o 70o.0o Total Depth: 6527.50tt MD, 4188.0011 TV 5 1/2' X 3 1/2' Liner - 6527.50 MD, 4188.00 TVD I I I I I I 0 500 1000 1500 2000 2500 -0 - -500 - -1000 -- -1500 - -2000 - -2500 - -3000 ~ O O II -- --3500 (~ o Z Scale: 1 inch = 50Oft Eastings Reference is True North Sperry-Sun Drilling Services Proposal Data - ID-138 WPs - 1D-138 WP1 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 0.00 0.000 0.000 -95.00 200.00 0.000 0.000 105.00 300.00 0.000 0.000 205.00 350.00 0.750 130.000 255.00 400.00 1.500 130.000 304.99 450.00 2.250 130.000 354.96 500.00 3.000 130.000 404.91 550.00 4.250 130.000 454.81 600.00 5.500 130.000 504.63 650.00 6.750 130.000 554.34 700.00 8.000 130.000 603.92 750.00 9.250 130.000 653.36 780.00 10.000 130.000 682.94 800.00 10.700 130.000 850.00 12.450 130.000 900.00 14.200 130.000 950.00 15.950 130.000 1000.00 17.700 130.000 1050,00 19.450 130.000 1100.00 21.200 130.000 702.61 751.59 800.24 848.52 896.38 943.77 990.66 1150.00 22.950 130.000 1036.99 1200.00 24.700 130.000 1082.73 1250.00 26.450 130.000 1127.83 1300.00 28.200 130.000 1172.25 1350.00 29.950 130.000 1215.94 Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959019.01 N 200.00 0.00 N 0.00 E 5959019.01 N 300.00 0.00 N 0.00 E 5959019.01 N 350.00 0.21 S 0.25 E 5959018,80 N 399.99 0.84 S 1.00 E 5959018.18 N 449,96 1.89 S 2.26 E 5959017.14 N 499.91 3.36 S 4.01 E 5959015.68 N 549.81 5.40 S 6.43 E 5959013.67 N 599.63 8.13 S 9.69 E 5959010.96 N 649.34 11.56 S 13.77 E 5959007.56 N 698.92 15.68 S 18.69 E 5959003.48 N 748.36 20.50 S 24.43 E 5958998.71 N 777.94 23.73 S 28.28 E 5958995.51 N 797,61 26.04 S 31.03 E 5958993.22 N 846.59 32.48 S 38.71E 5958986,84 N 895.24 39.89 S 47.54 E 5958979.50 N 943.52 48.25 S 57.50 E 5958971.22 N 991.38 57.55 S 68.59 E 5958962.01N 1038.77 67.79 S 80.79 E 5958951.87 N 1085.66 78.95 S 94.09 E 5958940.82 N 1131.99 91.03 S 108.49 E 5958928.86 N 1177.73 104.01S 123.96 E 5958916.00 N 1222.83 117.89 S 140.49 E 5958902.26 N 1267.25 132.64 S 158.07 E 5958887.65 N 1310.94 148.26 S 176.69 E 5958872.18 N Global Coordinates Eastings (ft) 560493.44 E 560493.44 E 560493.44 E 560493.69 E 560494.45 E 560495.71E 560497.48 E 56O499.92 E 560503.19 E 560507.31E 560512.26 E 560518.04 E 560521.91E 56O524.68 E 560532.42 E 560541.30 E 560551.33 E 560562.49 E 560574.77 E 560588.17 E 560602.66 E 560618.23 E 560634.88 E 560652.58 E 56O671.32 E Dogleg Rate (°/100ft) 0.000 0.000 1.500 1.500 1.500 1.500 2.500 2.500 2.500 2.500 2.500 2.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 0.00 0.00 0.00 0.32 1.28 2.89 5.13 8.23 12.40 17.63 23.92 31.28 36.19 39.72 49.56 60.85 73.61 87.80 103.41 120.44 138.87 158,67 179.84 202.34 226.17 Comment Start Dir @ 1.500°/100ft: 300.00ft MD, 300.00ft TVD Dir Rate Increase @ 2.500°/100ft: 500.00ft MD, 499.91ft TVD Dir Ratelncrease @ 3.500°/100ff:780.00ffMD, 777.94ff TVD Continued... 16 March, 2000 - 16:22 - I - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 1400.00 31.700 130.000 1258.88 1450.00 33.450 130.000 1301.01 1500.00 35.200 130.000 1342.30 1550.00 36.950 130.000 1382.71 1600.00 38.700 130.000 1422.21 1650.00 40.450 130.000 1460.74 1675.47 41.342 130.000 1480.00 1800.00 41.342 130.000 1573.49 1825.47 41.342 130.000 1592.62 1850.00 42.198 130.717 1610.91 1900,00 43.959 132.108 1647.43 1950,00 45.734 133.413 1682.88 2000.00 47.524 134.641 1717.21 2050.00 49.326 135.800 1750.39 2100.00 51.140 136.898 1782.38 2150.00 52.963 137.942 1813.12 2200.00 54.794 138.936 1842.60 2250.00 56.634 139.886 1870.76 2300.00 58.480 140.797 1897.58 2350.00 60.333 141.673 1923.03 2400.00 62.191 142.516 1947.07 2450.00 64.054 143.332 1969.67 2475.27 64.997 143.734 1980,54 2600.00 64.997 143.734 2033.26 2800.00 64.997 143.734 2117.79 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1353.88 164.73 S 196.31 E 5958855.87 N 560691.07 E 1396.01 182.03 S 216.93 E 5958838.73 N 560711.83 E 1437.30 200.15 S 238.53 E 5958820.79 N 560733.58 E 1477.71 219.08 S 261.08 E 5958802.04 N 560756.28 E 1517.21 238.78 S 284.57 E 5958782.52 N 560779.93 E 1555.74 259.26 S 308.97 E 5958762.25 N 560804.49 E 1575.00 269.98 S 321.75 E 5958751.63 N 560817.35 E 1668.49 322.85 S 384.76 E 5958699.27 N 560880.79 E 1687.62 333.67 S 397.65 E 5958688.55 N 560893.77 E 1705,91 344.25 S 410.10 E 5958678.07 N 560906.30 E 1742.43 366.84 S 435.70 E 5958655.69 N 560932.08 E 1777.88 390.78 S 461.58 E 5958631.96 N 560958.16 E 1812.21 416.05 S 487.71 E 5958606.90 N 560984.49 E 1845.39 442.60 S 514.05 E 5958580.57 N 561011.04 E 1877.38 470.41 S 540.58 E 5958552.97 N 561037.79 E 1908.12 499.44 S 567.25 E 5958524.15 N 561064,69 E 1937.60 529.66 S 594.04 E 5958494.15 N 561091,73 E 1965,76 561.03 S 620.91 E 5958462.99 N 561118.85 E 1992.58 593.52 S 647.84 E 5958430.72 N 561146.04 E 2018.03 627.08 S 674.78 E 5958397.38 N 561173.25 E 2042.07 661.67 S 701.71 E 5958363.01 N 561200.46 E 2064.67 697.25 S 728.60 E 5958327.65 N 561227,63 E 2075,54 715.60 S 742.16 E 5958309.41 N 561241.34 E 2128.26 806.74 S 809.03 E 5958218.81 N 561308.94 E 2212.79 952.89 S 916.25 E 5958073.53 N 561417.33 E Dogleg Rate (°/100ft) 3.500 3.500 3.500 3.500 3.500 3.500 3.500 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.0OO 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 251,29 277.68 305.33 334.20 364.26 395.50 411.85 492.51 509.01 525.05 558.69 593.55 629,61 666.80 705.08 744.42 784.75 826,04 868.23 911.26 955.10 999.68 1022.47 1135.41 1316.51 Comment End Dir: 1675.47ft MD, 1575.00ft TVD Start Dir @ 4.000°/100ft: 1825.47ft MD, 1687.62ft TVD End Dir: 2475.27ft MD, 2075.54ft TVD Continued... 16 March, 2000 - 16:22 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 3000.00 64.997 143.734 2202.33 3200.00 64.997 143.734 2286.86 3400.00 64.997 143.734 2371.39 3600,00 64,997 143.734 2455.92 3800.00 64,997 143.734 2540.45 4000.00 64.997 143.734 2624.99 4200.00 64.997 143,734 2709.52 4400.00 64.997 143.734 2794.05 4600.00 64,997 143.734 2878.58 4800.00 64.997 143.734 2963.12 5000.00 64,997 143.734 3047.65 5200.00 64.997 143.734 3132.18 5276.35 64.997 143.734 3164.45 5300.00 64.052 143.716 3174.62 5350.00 62.052 143.678 3197.28 5400.00 60.052 143,638 3221.48 5450.00 58.053 143.597 3247.19 5500.00 56.053 143.554 3274.38 5550.00 54.053 143.509 3303.02 5600.00 52.054 143.461 3333.08 5650.00 50.054 143.411 3364.50 5700.00 48.054 143.357 3397.27 5750.00 46.055 143.301 3431.33 5800.00 44.055 143.240 3466.65 5850.00 42.056 143.175 3503.18 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2297.33 1099.03 S 1023.47 E 5957928.25 N 561525.72 E 2381.86 1245.17 S 1130.69 E 5957782.98 N 561634.11 E 2466.39 1391.32 S 1237.91 E 5957637.70 N 561742.51 E 2550.92 1537.46 S 1345.13 E 5957492.42 N 561850.90 E 2635.45 1683.61 S 1452,35 E 5957347.15 N 561959.29 E 2719,99 1829.75 S 1559.57 E 5957201.87 N 562067.69 E 2804.52 1975.90 S 1666.79 E 5957056.60 N 562176.08 E 2889.05 2122.04 S 1774.01 E 5956911.32 N 562284.47 E 2973.58 2268.18 S 1881.23 E 5956766.04 N 562392.87 E 3058,12 2414.33 S 1988.45 E 5956620.77 N 562501.26 E 3142.65 2560.47 S 2095.67 E 5956475.49 N 562609.65 E 3227.18 2706.62 S 2202.89 E 5956330.21 N 562718.05 E 3259.45 2762.41 S 2243.82 E 5956274.75 N 562759.43 E 3269.62 2779.62 S 2256.45 E 5956257.64 N 562772.19 E 3292.28 2815.54 S 2282.84 E 5956221.94 N 562798.87 E 3316.48 2850.78 S 2308.76 E 5956186.91 N 562825.08 E 3342.19 2885.30 S 2334.20 E 5956152.59 N 562850.79 E 3369.38 2919.06 S 2359.11 E 5956119.03 N 562875.97 E 3398.02 2952.02 S 2383.47 E 5956086.27 N 562900.60 E 3428.08 2984.13 S 2407.25 E 5956054.35 N 562924.63 E 3459.50 3015.36 S 2430.41 E 5956023.31 N 562948.05 E 3492.27 3045.68 S 2452.93 E 5955993.18 N 562970.81 E 3526.33 3075.03 S 2474.79 E 5955964.00 N 562992.91 E 3561.65 3103.39 S 2495.95 E 5955935.81 N 563014.30 E 3598.18 3130.73 S 2516.40 E 5955908.64 N 563034.96 E Dogleg Rate (°/100ft) 0.ooo 0.000 o.0oo o.0oo o.ooo o.ooo o.ooo o.ooo o.ooo o.ooo 0.ooo o.000 o.ooo 4.000 4.000 4.000 4.000 4.oo0 4.000 4.000 4.000 4.000 4.000 4.000 4.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 1497.61 1678.70 1859.80 2040.89 2221.99 2403.08 2584.18 2765.28 2946.37 3127.47 3308.56 3489.66 3558.80 3580.12 3624.65 3668.37 3711.21 3753.14 3794.09 3834.02 3872.87 3910.61 3947.19 3982.56 4016.67 Comment Start Dir @ 4.000°/100ft: 5276.35ft MD, 3259.45ft TVD Continued... 16 March, 2000 - 16:22 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings (ft) (ft) (ft) (ft) (ft) (ft) 5900.00 40.056 143.104 3540,89 3635.89 3157.00 S 2536.10 E 5955882,53 N 5922,22 39.168 143.071 3558.00 3653.00 3168.33 S 2544.60 E 5955871.27 N 5950.00 38.057 143.028 3579.71 3674.71 3182.18 $ 2555.02 E 5955857.50 N 6000.00 36,057 142.944 3619.61 3714.61 3206.24 S 2573.16 E 5955833,59 N 6006.66 35.791 142.932 3625.00 3720.00 3209.36 S 2575.52 E 5955830.49 N 6050.00 34.058 142.852 3660,54 3755.54 3229.15 S 2590.49 E 5955810.82 N 6100,00 32.059 142.749 3702.44 3797.44 3250,87 S 2606.97 E 5955789.23 N 6107.73 31.750 142.733 3709.00 3804.00 3254.12 S 2609.45 E 5955786.00 N 6150.00 30.060 142.656 3745,27 3840.27 3271.39 S 2622.61 E 5955768.84 N 6200.00 28.060 142.555 3788.97 3883.97 3290.68 S 2637.35 E 5955749.66 N 6250.00 26.061 142.439 3833,50 3928.50 3308.73 S 2651.20 E 5955731.73 N 6300.00 24.062 142.306 3878.79 3973.79 3325.50 S 2664.13 E 5955715.06 N 6315.53 23.441 142.260 3893.00 3988.00 3330.45 S 2667.96 E 5955710.14 N 6350.00 22.062 142.177 3924.79 4019.79 3340.99 S 2676.12 E 5955699.67 N 6400.00 20.063 142.037 3971.45 4066.45 3355.17 S 2687.16 E 5955685.58 N 6450.00 18.064 141.867 4018.70 4113.70 3368.03 S 2697.22 E 5955672.80 N 6500.00 16,065 141.657 4066.50 4161.50 3379.55 S 2706.30 E 5955661.35 N 6527.50 14.965 141.518 4093.00 4188.00 3385.32 S 2710.87 E 5955655.62 N Global Coordinates Eastings (ft) 563054.87 E 563063.47 E 563074.00 E 563092,33 E 563094.71E 563109.84 E 563126.50 E 563129.00 E 563142.30 E 563157.20 E 563171.19 E 563184.25 E 563188.12 E 563196.37 E 563207.52 E 563217.69 E 563226.86 E 563231.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1D-138. Northings and Eastings are relative to 1 D-138. Magnetic Declination at Surface is 26.703° (24-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1 D-138 and calculated along an Azimuth of 141.313° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6527.50ft., Dogleg Rate (°/100ft) 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4,000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 4049.49 4063.65 4080.98 4111.10 4115.00 4139.81 4167.07 4171.15 4192.86 4217.14 4239.88 4261.05 4267.30 4280.63 4298.60 4314.93 4329.60 4336.96 Comment D B A3 1D-138 TARGET A1 Total Depth: 6527.50ft MD, 4188.00ft TVD 5 1/2" X 3 1/2" Liner 16 March, 2000 - 16:22 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska The Bottom Hole Displacement is 4336.96ft., in the Direction of 141.313° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 300.00 300.00 0.00 N 0.00 E 500.00 499.91 3.36 S 4.01 E 780.00 777.94 23.73 S 28.28 E 1675.47 1575.00 269.98 S 321.75 E 1825.47 1687.62 333.67 S 397.65 E 2475.27 2075.54 715.60 S 742.16 E 5276.35 3259.45 2762.41 S 2243.82 E 6527.50 4188.00 3385.32 S 2710.87 E Comment Start Dir @ 1.500°/100ft: 300.00ft MD, 300.00ft TVD Dir Rate Increase @ 2.500°/100ft: 500.00ft MD, 499.91ft TVD Dir Rate Increase @ 3.500°/100ft: 780.00ft MD, 777.94ft TVD End Dir: 1675.47ft MD, 1575.00ft TVD Start Dir @ 4.000°/100ft: 1825.47ft MD, 1687.62ft TVD End Dir · 2475.27ft MD, 2075.54fl TVD Start Dir @ 4.000°/100ft · 5276.35ft MD, 3259.45ft TVD Total Depth · 6527.50ft MD, 4188.00ft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) 5922.22 3653.00 3558.00 3168.33 S 6006.66 3720.00 3625.00 3209.36 S 6107.73 3804.00 3709.00 3254.12 S 6315.53 3988.00 3893.00 3330.45 S Eastings Formation Name (ft) 2544.60 E D 2575.52 E B 2609.45 E A3 2667.96 E A1 Alaska State Plane 4 Kuparuk 1D Continued... 16 March, 2000 - 16:22 - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-138 WPs - 1D-138 WP1 Revised: 15 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 6527.50 Targets associated with this wellpath Target Name 1 D-138 TARGET Vertical Depth Casing Detail (ft) 4188.oo 5 1/2" X 3 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3804.00 3254.12 S 2609.45 E 3709.00 5955786.00 N 563129.00 E 70°17'22.9534"N 149° 29'20.3203"W Target Target Shape Type Point 16 March, 2000 - 16:22 - 6 - DrillQuest 1.05.05 Sperry-Sun Alaska Anticollision Report : c0m~ny:: ...... :::: ::: :A~0:Alask~lnci ::: ...... ::::::::: ::: ...... Date:: :O3/2412000 Time: 12:47:04 Page: 1 :Field:;:: ...... K~Pa~k Ri~e~ u~it : i ........... ] : ~fe~ Site~ ; i : ~°~dinatetTqE):Reference: Well: 1D-138 WPs, True No~h R~fe~ce ~B~ ~ ~P~:: ~e~hi (T~) Reference: 1D-138 WPs 95.0 above Mean Sea Level NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Definitive Plan Interpolation Method: MD Interval: 100.000 ft Error Model: ISCWSA Ellipse Depth Range: 0.000 to 6527.881 ft Scan Method: High Side + Azimuth Maximum Radius:q0000.000 ft Error Surface: Ellipse Survey Program for Definitive Wellpath Date: 02/28/2000 Validated: No Version: 0 Planned From To Survey Toolcode ToolName ft ft 0.000 5350.950 Planned: 1D-138 wPq vq MWD MWD- Standard Summary ]: ] :ff ff ft ft Kuparuk 1D Pad 1 D-07 Kuparuk 1D Pad 1 D-08 Kuparuk 1D Pad 1 D-10 Kuparuk 1D Pad 1 D-11 Kuparuk 1D Pad 1 D-128 Kuparuk 1D Pad 1D-129 Kuparuk 1D Pad 1 D-130 Kuparuk 1D Pad 1D-131 Kuparuk 1D Pad 1D-132 Kuparuk 1D Pad 1D-133 Kuparuk 1D Pad 1D-133 Kuparuk 1D Pad 1D-134 Kuparuk 1D Pad 1 Do135 Kuparuk 1D Pad 1 D-139 WPs 1 D-07 V2 1 D-08 V12 1D-10 V2 1D-11 V4 1 D-128 V2 1D-129 V2 1D-13O V2 1D-131 V2 1D-132 V2 1D-133 V2 1D-133PB1 V2 1D-134 V2 1D-135 V2 392.375 300.000 165.805 5.787 160.019 Pass: Major Risk 386.360 400.000 44.554 5.489 39.065 Pass: Major Risk 578.495 600.000 85.644 9.554 76.090 Pass: Major Risk 1483.094 1500.000 69.702 51.266 18.435 Pass: Major Risk 824.818 900.000 315.261 15.845 299.416 Pass: Major Risk 723.337 800.000 245.747 16.347 229.399 Pass: Major Risk 380.244 400.000 240.817 5.149 235.668 Pass: Major Risk 721.648 800.000 180.037 17.687 162.350 Pass: Major Risk 735.348 800.000 141.662 16.800 124.862 Pass: Major Risk 572.032 600.000 199.795 7.979 191.816 Pass: Major Risk 572.032 600.000 199.795 7.979 191.816 Pass: Major Risk 934.116 1000.000 136.132 19.601 116.531 Pass: Major Risk 381.823 400.000 120.569 5.043 115.526 Pass: Major Risk ID-139 V3 Plan: 1D-139 500.299 500.000 13.445 1.744 11.701 Pass: Minor Risk Site: Kuparuk 1D Pad Well: 1D-07 Rule Assigned: Major Risk Wellpath: 1D-07 V2 Inter-SiteError: 0.000 ft :::::MD ;~; ;MD::;: ::: TVD ::: :::Ref ]:::;Offsb]t : TFO~I::TFO:HS Casing Distance Area Deviation Warning :::: :fi: ft ::::ff ::ft ::: :fi ;:: d~ : :: in ft ft ft 195.000 195.000 100.000 201.000 0.053 0.000 359.38 359.38 294.999 294.999 200.000 300.999 0.163 0.000 359.25 359.25 392.375 392.366 300.000 400.998 0.218 0.224 358.96 228.96 489.503 489.425 400.000 500.998 0.195 0.485 358.10 228.10 584.720 584.411 500.000 600.983 0.196 0.708 356.30 226.30 679.043 678.159 600.000 700.824 0.325 0.945 352.83 222.83 772.096 770.150 700.000 800.240 0.536 1.145 347.40 217.40 861.044 857.367 800.000 898.895 0.819 1.456 339.90 209.90 946.820 940.463 900.000 996.367 1.151 1.757 330.88 200.88 1028.971 1018.899 1000.000 1092.260 1.529 2.098 321.18 191.18 1106.836 1092.026 1100.000 1186.314 1.940 2.518 311.79 181.79 1180.545 1160.004 1200.000 1278.242 2.393 2.925 303.43 173.43 1249.539 1222.414 1300.000 1367.897 2.864 3.378 296.37 166.37 1314.138 1279.677 1400.000 1455.033 3.336 3.794 290.48 160.48 1375.697 1333.108 1500.000 1539.839 3.832 4.136 285.57 155.57 1434.268 1382.843 1600.000 1622.158 4.337 4.523 281.39 151.39 1500.000 1437.302 1700.000 1701.261 4.930 4.997 277.76 147.76 1539.457 1469.267 1800.000 1777.009 5.323 5.509 274.59 144.59 1586.030 1506.266 1900.000 1849.390 5.786 6.028 271.82 141.82 1629.629 1540.161 2000.000 1919.480 6.243 6.539 269.45 139.45 1675.474 1575.000 2100.000 1989.465 6.736 6.732 267.58 137.58 1727.215 1613.846 2200.000 2060.071 7.310 6.710 266.10 136.10 1784.494 1656.850 2300.000 2130.936 7.946 6.808 264.88 134.88 1838.876 1697.643 2400.000 2202.415 8.551 6.917 264.01 133.62 1886.763 1732.864 2500.000 2274.349 9.082 7.001 263.64 131.89 165.384 1.660 163.724 Pass 165.308 3.489 161.819 Pass 165.805 5.788 160.019 Pass 168.272 7.961 160.319 Pass 171.525 10.060 161.546 Pass 174.657 12.583 162.331 Pass 178.117 15.225 163.445 Pass 184.469 18.363 167.183 Pass 195.698 21.573 176.035 Pass 214.007 24.989 192.048 Pass 241.664 28.669 217.236 Pass 277.562 32.254 250.531 Pass 322.413 36.057 292.413 Pass 374.220 39.707 341.259 Pass 429.961 43.008 394.259 Pass 489.267 46.557 450.601 Pass 553.108 50.532 511.056 Pass 621.188 53.771 576.162 Pass 693.326 57.108 645.299 Pass 768.513 60.502 717.554 Pass 846.055 63.082 792.730 Pass 924.861 65.675 868.835 Pass 1004.215 68.510 945.275 Pass 1084.522 71.521 1022.454 Pass 1165.360 74.054 1100.928 Pass Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Begin Primary One Stage Cement Job to Surface Cement / above Port / Collar / (1000' Tva)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Cement below Port Collar (1000' TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Continue with Completion West Sak Monobore Injector 5-1/2" TAM Port Collar The goal for using this tool is to eliminate use of a two stage cementing collar while still ensuring cement is successfully circulated to surface. This is yet another way to reduce rig time on West Sak wells while still providing operational integrity. This tool will only be opened if cement does not reach the surface with a single stage cement job and also is out of top job range. The decision to use the port collar will be made by the ARCO Drilling Foreman on location, This tool is basically a sliding sleeve which is opened with a "Combo Tool" that has packoffs on either side of 1" ports. The Combo Tool is run in on drillpipe until latching into a profile on the collar which places the ports on the combo tool across from the sliding sleeve of the port collar. Approximately 15,000 lbs. of weight is applied to shift the collar open. The packoffs ensure that cement is pumped out the ports into the annulus. When the cement job is complete, the Combo Tool is pulled out of the well. The port collar provides a full ID upon closing. Therefore no drill out is required after cementing. If conditions indicate a good job, the tubinq should then be run without cleanout run. Detailed operational procedures are enclosed. The Port Collar should be placed at approximately 1000' TVD. This depth was chosen because it is most likely out of top job range, but is still accessible with drillpipe in a reasonable time. Therefore it is recommended that if the Drilling Foreman believes that the top of cement is deeper than 1000' TVD the Port Collar should be used, otherwise a top job should be performed. An estimate of the top of cement can be made through the final slow circulating pressure before bumping the plug. In addition, a dye or a small amount of LCM should be mixed with the spacer to give an indication of top of cement. In order to facilitate a quick turn around should the Port Collar be used, it is also recommended that the Combo Tool be made up on a pup joint and be ready on the catwalk and approximately 12 stands of 3 Y2" tubing be racked back. As mentioned above, the tool does require approximately 15,000 lbs to open, therefore some heavy weight pipe may need to be run. A top job is the preferred remedial action to take if at all possible in the event cement does not reach the surface. The use of a Port Collar should be the last option for achieving cement to surface. The AOGCC must approve all top jobs in advance. Pre-approval should be considered since the time to make a decision whether to use the Port Collar or a Stage job will be small. Combo Tool and Port Collar Running Procedure 1. Check that all materials are at the rig site · 5 Y2" TAM Combo Tool, with 2 7/8" EUE Box by Pin and 5 Y2" 15.5 ppf Packer Cups · 5 Y2" TAM Port Collar with 5 ~" BTC Box x Pin Connections · 3 Y~" Choke Sub with 2 7/8" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers 2. Ensure that all connections are compatible or there are appropriate crossovers available 3. Pick up and run 5 Y~" 15.5 ppf casing with Port Collar placed at 1000' TVD 4. If the Drilling Foreman determines that it is necessary to use the Port Collar, run in the hole with the 3 Y2" tubing as a workstring until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. · In order to trip in with the 3 ~" work string and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. 5. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure 6. Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. 7. Establish circulation rate and pressure 8. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing 9. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar 10. Pressure up on workstring to confirm collar is closed 11. With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar 12. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub 13. Reverse out excess cement as required 14. Pull out of hole with tools Greater Kuparuk Area Casing Pressure Test Standard Draft 4 The AOGCC requires a 30 minute casing pressure test prior to drilling out the float equipment. Current AOGCC regulations require surface casings to be tested to 1500 psi or 0.25 psi/ft, whichever is greater. This test needs to be charted for the AOGCC. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Casing Test Procedure Pressure test the surface casing to the value specified in the well plan, above and below the stage collar, if one has been run. Hold each of these tests for 10 minutes to insure the stage collar is completely closed. The AOGCC does not require this test to be charted. Check the well plan for any site specific drill out details. 2. Run in hole to top of baffle plate or float collar, whichever occurs first. Establish circulation and insure well is stable for the 30 minute test. Pressure test surface casing to the value outlined in the well plan for 30 minutes. This test needs to be charted for the AOGCC. Pressure vs. volume needs to be plotted for AAI records and as a minimum volume line for the upcoming LOT/FIT. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record the pump pressure every two pump strokes until the pressure specified in the well plan is reached (this will insure enough data points on the LOT/FIT). Monitor shut in casing pressure for 30 minutes. Make sure test is being accurately recorded on a chart. Check surface equipment for leaks if pressure drops more than 10 percent in 30 minutes. If surface leaks are discovered repair them and do the casing test over. If no surface leaks are found and casing pressure continues to bleed off contact, the AAI Drilling Engineer assigned to the rig, prior to drilling out the casing float equipment. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 4. After achieving a successful casing test. Drill out remaining cement and all float equipment. Clean out any existing rat hole. Drill 20 feet of new hole. Perform a LOT/FITper the standard procedure that follows. RLM 7/31/98 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kupamk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known requked mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kupamk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. 5. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 March 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: West Sak 1D-138 Surface Location: Target Location: Bottom Hole Location: 648' FNL, 598' FEL, Sec 23, T11 N, R10E 1376' FSL, 2009' FWL, Sec. 24, T11 N, R10E 1245' FSL, 2110' FWL, Sec. 24, T11N, R10E Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1 D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of 1D Pad. The well is designated as a monobore injector using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. The well will be drilled and completed using Nordic Rig 3. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25,035 (a) (1) and (b). 6) Complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) 11) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARC©'s designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is April 24, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Tom McKay at 265-6890 or Chip Alvord at 265-6120. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: cc: KRU 1 D-138 Well File Chip Alvord Tom McKay ATO-1030 ATO-1 O6O Anch'0'r'sge~ AK,' 9951.0 ONE. HUNDRED DOLLARS AND NO CENTS Pa¥~bl~'.'%?h~ugh 010O92O To the order of: STATE OF ALASKA ALAS}C~, OIL £. GAS CONSERVATION COMMISSION I 3001 PORCUPINE DRIVE AN C}{ORAGE AK 99501 03-21-00 Date O q **************100.00' Amount Void after 90 days - ~ TWo signatures required for amounts over $2S,000.00 ,, , WELL PERMIT CHECKLIST COMPANY WELL NAME/~-'/~? FIELD & POOL ADMINISTRATION APPR DATE/ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... (~ N 19. Casing designs adequate for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ ~ N DATE 26. BOPE press rating appropriate; test to ~'OO C~ psig. (~ N /fl-.,/<~...) 27. Choke manifold complies w/APl RP-53 (May 84) N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. PROGRAM: exp dev redrll .. serv ,.,.2~ wellbore seg ~ L AREA ~',~'~ UNIT# ,/',/'~_,~,,'~ N ann. disposal para req ~ ON/OFF SHORE Y® GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~Y N ' 31. Data presented on potential overpressure zones ....... ~Y ~,/' ~ .~,7TM'/// 32. Seismic analysis of shallow gas zones .............. AI3P. R DANTE 2 33. Seabed condition survey (if off-shore) ............. ~"/~.', ~/~,,)/~:::)., 34. Contact name/phone for weekly progress reports [exploratory oMy]/ Y N ANNULAR DISPOSAL35. With proper cementing records, this plan ~Z)~C.j~c.p,.¢,~ (~£~-~...c-~(__ ~..P__.~ u.~-zT't~ - ~':' - v~,~-H~. 0d,~z'~ -r-o ,D~sp~5~ ~ ~---- (A) will contain waste in a suitable receiving zone; ....... Y N ~,~oe.r.~ ~ f~'~'~.-,-~.oe,<~o¢~..O Ar~Oz-! o~, ~- APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlC/Annular COMMISSION: TEM (~ CO ~ ¢/~ ~ Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ., No special 'effort has been made to chronologically organize this category of information. (J (L- Å ~ \\ - 0 væ Memory Multi-Finger Caliper Log Results Summary I,' Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 18, 2005 7012 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1 D-138 Field: Kuparuk State: Alaska API No.: 50-029-22957-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 5,884 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the "OS" Nipple @ 5,782' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The 3.5" tubing and liner logged appear to be in good to poor condition with respect to corrosive damage, with a maximum wan penetration of 81 % in joint 89 (2,831'). Wall penetrations ranging from 20% to 81 % are recorded in 157 of the 192 joints logged. The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Corrosion Corrosion Corrosion Corrosion Corrosion ( 81%) ( 74%) ( 72%) ( 69%) ( 68%) Jt. Jt. Jt. Jt. Jt. 89 @ 91 @ 95 @ 105 @ 65 @ 2,831 Ft. (MD) 2,911 Ft. (MD) 3,013 Ft. (MD) 3,350 Ft. (MD) 2,093 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing and liner loggeq. 8CÁN~~¡c:r. ("'.'... Eo 2 I:) 2' (]IJí:' !:'C~,_ d .,) d _ \ ü I Field Engineer: II1/. McCrossan Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~s \J II' Well: Field: Company: Country: 10-138 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) _ penetration body 200 !IIIIi! metal loss body 150 100 50 o 0 to 1% 1 to 10% 1 0 to 20 to 40 to ove r 20% 40% 85% 85% Number of joints analysed (total = 192) pene. 0 6 29 44 113 0 loss 1 7 1 75 0 0 0 0 Damage Configuration ( body) 150 100 50 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ¡ble hole Number of joints damaged (total = 178) 50 109 19 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 18, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) II!".D1!!!I metal loss body 50 _ penetration body o O~ =- -æ; .ææ:.. c:::::. c=- æ§;: =- -æ=' T 100 ~ - ~ 48k' ," \ 98 _ =:... r ,"r,~' ,J;,-::: \~\ ft\!: 148 . , ..~\ ; {\, \ GLM 1 '\ , \ ' =~ ~. ~ ~ \ "' -, Bottom of Survey = 185 Analysis Overview page 2 , 'J PDS'KEPORT JOINTTABULATION~~HEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 0-1 38 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Oate: August 18, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Oamage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) (Yo (Ins.) 0 50 100 .1 51 0 0.04 14 .., 2.92 PUP Shallow corrosion. .::> .2 55 0 0.05 19 4 2.88 PUP Shallow corrosion. Lt. Oeposits. .3 62 0 0.03 13 1 2.90 PUP Shallow corrosion. 1 70 0 0.02 9 .2 2.91 2 102 0 0.04 14 2.90 Shallow pitting. 3 134 0 0.03 11 2.91 4 165 0 0.04 16 .2 2.91 Shallow pitting. 5 197 0 0.04 14 .2 2.91 Shallow pitting. 6 226 0 0.03 13 .2 2.90 Shallow pitting. Lt. Oeposits. 7 257 0 0.03 10 2.92 8 289 0 0.03 13 2 2.91 Shallow pitting. 9 320 0 0.03 12 .2 2.92 Shallow pitting. 10 351 0 0.03 11 2.92 11 383 0 0.03 11 .1 2.92 12 414 0 0.04 14 2.91 Shallow pitting. 13 445 0 0.03 12 .1 2.92 14 477 0 0.03 13 1 2.92 Shallow pitting. 15 508 0 0.03 13 .1 2.92 Shallow pitting. 16 540 0 0.02 9 1 2.91 17 570 0 0.03 12 1 2.93 18 601 0 0.03 10 1 2.91 19 633 0 0.04 14 2 2.92 Shallow pitting. 20 664 0 0.04 14 2 2.92 ShÇl.llow pitting. 21 696 0 0.03 13 2 2.92 Shallow pitting. 22 727 0 0.03 10 .1 2.92 23 759 0 0.04 14 2.92 Shallow pitting. 24 790 0 0.03 13 2.91 Shallow pitting. 25 822 0 0.03 11 2 2.92 26 853 0 0.03 11 .1 2.92 27 885 0 0.03 12 .1 2.91 28 916 0 0.02 9 1 2.92 29 948 0 0.03 13 1 2.92 Shallow pitting. 30 979 0 0.06 25 2 2.91 Isolated pitting. 31 1010 0 0.07 28 .1 2.92 Isolated pitting. Lt. Oeposits. 32 1042 0 0.07 26 2 2.91 Isolated pitting. 33 1073 0 0.08 32 2 2.92 Isolated pitting. 34 1104 0 0.08 30 3 2.92 Isolated pitting. 35 1136 0 0.09 34 2 2.92 Isolated pitting. 36 1167 0 0.08 33 2 2.92 Isolated pitting. 37 1198 0 0.05 19 1 2.92 Shallow pitting. 38 1229 0 0.10 38 3 2.91 Isolated pitting. 39 1257 0 0.04 15 1 2.92 Shallow corrosion. 40 1289 0 0.05 18 3 2.92 Shallow pitting. 41 1320 0 0.06 22 .1 2.92 Isolated pitting. 42 1351 0 0.07 28 2.91 Isolated pitting. 43 1382 0 0.14 54 2 2.92 Corrosion. 44 1413 0 0.10 39 3 2.91 Isolated pitting. 45 1445 0 0.12 48 2 2.92 Isolated pitting. 46 1476 0 0.13 51 3 2.91 Isolated pitting. 47 1508 0 0.12 47 3 2.90 Isolated pitting. I Penetration Body ~i¡¡:~J Metal Loss Body Page 1 PDS'~~ KfPORT JOI NT TABU LA TION( :)H EET Pipe: Body Wall: Upset Wall: N ominaII.O.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body °/0 Loss 1.0. (Ins.) (Ins.) (J;J (Ins.) 48 1539 0 0.11 43 3 2.92 49 1570 0 0.12 46 3 2.90 50 1602 0 0.10 40 3 2.92 51 1633 0 0.15 57 4 2.92 52 1664 0 0.11 42 3 2.91 53 1696 0 0.12 46 4 2.91 54 1727 0 0.10 40 :2 2.91 55 1758 0 0.14 57 3 2.92 56 1790 0 0.08 31 :2 2.91 57 1821 0 0.13 51 4 2.92 58 1853 0 0.06 23 :2 2.91 59 1882 0 0.10 41 4 2.92 60 1913 0 0.12 48 4 2.90 61 1944 0 0.16 62 3 2.90 62 1976 0 0.11 44 4 2.92 63 2007 0 0.13 53 3 2.92 64 2038 0 0.14 53 4 2.91 65 2070 0 0.17 68 5 2.91 66 2101 0 0.13 51 4 2.92 67 2133 0 0.13 52 5 2.90 68 2164 0 0.13 52 6 2.89 69 2195 0 0.14 55 4 2.92 70 2227 0 0.14 57 4 2.90 71 2258 0 0.11 44 4 2.91 72 2288 0 0.14 54 5 2.93 73 2320 0 0.12 49 5 2.92 74 2351 0 0.16 64 4 2.93 75 2381 0 0.11 45 3 2.91 76 2413 0 0.11 44 4 2.92 77 2444 0 0.15 59 4 2.92 78 2475 0 0.14 54 4 2.93 79 2506 0 0.16 64 6 2.91 80 2538 0 0.12 46 4 2.91 81 2569 0 0.12 46 3 2.92 82 2601 0 0.13 53 3 2.92 83 2632 0 0.14 54 3 2.92 84 2663 0 0.13 50 3 2.88 85 2695 0 0.17 66 4 2.88 86 2726 0 0.16 64 4 2.90 87 2758 0 0.12 45 5 2.90 88 2788 0 0.14 54 4 2.91 89 2820 0 0.21 81 5 2.91 90 2851 0 0.17 68 4 2.92 91 2883 0 0.19 74 6 2.89 92 2914 0 0.15 59 5 2.91 93 2946 0 0.16 64 4 2.86 94 2977 0 0.15 58 4 2.87 95 3007 0 0.18 72 7 2.89 96 3038 0 0.16 62 4 2.89 97 3070 0 0.15 58 5 2.89 Well: Field: Company: Country: Survey Date: 10-138 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2005 Comments Isolated pitting. Corrosion.. Corrosion.. Corrosion.. Corrosion.. Lt. Oeposits. Corrosion. Lt. Oeposits. Isolated pitting. Corrosion.. Isolated pitting. Lt. Deposits. Corrosion. Corrosion. Lt. Oeposits. Corrosion. Lt. Deposits. Corrosion. Isolated pitting. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Lt. Oeposits. Corrosion. Corrosion.. Corrosion. Corrosion. Isolated pitting. Corrosion. Isolated pitting. Corrosion. Corrosion. Corrosion.. Lt. Oeposits. Corrosion. Corrosion. Corrosion. Isolated pitting. Lt. Oeposits. Corrosion. Lt. Oeposits. Isolated pitting. Corrosion. Lt. Oeposits. Isolated pitting. Corrosion.. Corrosion.. Corrosion. Lt. Oeposits. Corrosion. Lt. Oeposits. Corrosion. Lt. Deposits. Corrosion.. Corrosion. Lt. Oeposits. Corrosion.. Lt. Deposits. Corrosion. Page 2 Oamage Profile (% wall) o 50 100 ... .. I I I I . Penetration Body ~j Metal Loss Body PDS1KEPORT JOINT TABULATION(~HEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 0-1 38 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Oate: August 18, 2005 Joint Jt. Oepth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss 1.0. Comments (Ins.) (Ins.) %J (Ins.) 98 3101 0 0.13 50 5 2.90 Corrosion. Lt. Oeposits. 99 3133 0 0.14 57 4 2.90 Corrosion.. 100 3164 0 0.17 65 5 2.90 Corrosion.. 101 3196 0 0.11 43 3 2.89 Isolated pitting. 102 3227 0 0.12 46 4 2.91 Corrosion. 103 3258 0 0.12 49 5 2.91 Corrosion. 104 3289 0 0.13 53 5 2.91 Corrosion. 105 3321 0 0.18 69 5 2.91 Corrosion. 106 3353 0 0.14 54 3 2.91 Isolated pitting. 107 3384 0 0.13 50 4 2.91 Corrosion. 108 3415 0 0.12 49 4 2.90 Corrosion. 109 3445 0 0.15 60 5 2.91 Isolated pitting. 110 3476 0 0.13 52 4 2.90 Corrosion. 111 3508 0 0.15 59 6 2.91 Corrosion. Lt. Oeposits. 112 3539 0 0.13 50 3 2.91 Corrosion. Lt. Deposits. 113 3571 0 0.12 49 5 2.89 Corrosion. Lt. Oeposits. ~14 3599 0 0.14 57 4 2.91 Corrosion.. 115 3630 0 0.14 54 3 2.91 Corrosion.. 116 3662 0 0.14 56 4 2.90 Corrosion. 117 3692 0 0.16 63 4 2.91 Corrosion.. 118 3723 0 0.13 53 4 2.91 Corrosion. 119 3755 0 0.14 54 4 2.91 Corrosion.. 120 3786 0 0.13 53 5 2.91 Corrosion. 121 3817 0 0.17 66 5 2.91 Corrosion.. 122 3847 0 0.12 46 5 2.92 Corrosion. 123 3879 0 0.13 52 4 2.92 Corrosion.. 124 3910 0 0.14 54 4 2.91 Corrosion. 125 3941 0 0.14 54 4 2.91 Corrosion. 126 3972 0 0.12 49 4 2.90 Corrosion.. 127 4004 0 0.10 41 3 2.91 Corrosion.. 128 4035 0 0.11 45 3 2.91 Corrosion. 129 4066 0 0.13 51 4 2.91 Corrosion. Lt. Oeposits. 130 4098 0 0.11 42 3 2.91 Corrosion. Lt. Oeposits. 131 4129 0 0.12 48 3 2.91 Isolated pitting. 132 4160 0 0.12 48 4 2.89 Corrosion. Lt. Deposits. 133 4189 0 0.13 50 4 2.89 Corrosion.. Lt. Oeposits. 134 4219 0 0.12 46 4 2.88 Corrosion.. 135 4251 0 0.09 35 2 2.93 Line of corrosion. 136 4282 0 0.11 45 3 2.90 Line of corrosion. 137 4313 0.05 0.10 41 3 2.91 Isolated pitting. 138 4344 0 0.13 52 4 2.92 Corrosion.. 139 4376 0 0.09 35 3 2.92 Line of corrosion. 140 4407 0 0.11 43 3 2.90 Corrosion. 141 4438 0 0.12 46 3 2.90 Corrosion.. 142 4470 0 0.12 4ß 3 2.89 Corrosion. 143 4500 0 0.11 43 3 2.92 Isolated pitting. 144 4530 0 0.12 46 3 2.92 Corrosion. 145 4561 0 0.12 49 3 2.90 Isolated pitting. 146 4593 0 0.14 54 3 2.91 Corrosion. 147 4624 0 0.12 49 4 2.92 Corrosion. Page 3 Oamage Profile (% wall) o 50 100 I .. .. .. .. I I . Penetration Body ~ Metal Loss Body Pipe: Body Wall: Upset Wall: Nominal 1.0.: Joint No. 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 181 181.1 181.2 181.3 182 182.1 183 183.1 183.2 1 83.3 184 185 ~. ;~ PDSKEPORT JOINT TABULATION~HEET 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Jt. Oepth (Ft.) 4655 4686 4716 4747 4779 4810 4840 4872 4904 4933 4965 4996 5028 5059 5091 5121 5153 5184 5216 5247 5278 5309 5340 5372 5403 5434 5465 5497 5528 5559 5590 5621 5653 5684 5715 5729 5736 5751 5782 5783 5814 5821 5836 5846 5877 Pen. Upset (Ins.) o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o Pen. Body (Ins.) 0.10 0.11 0.11 0.11 0.11 0.12 0.11 0.11 0.12 0.11 0.10 0.10 0.10 0.10 0.11 0.12 0.09 0.08 0.12 0.09 0.10 0.09 0.09 0.10 0.10 0.10 0.11 0.10 0.11 0.10 0.09 0.09 0.10 0.09 0.10 o 0.09 0.12 o 0.09 0.08 o 0.09 0.10 0.09 Pen. Metal % Loss 0/0 39 2 44 5 44 3 42 2 43 4 46 4 42 :2 44 4 48 6 42 4 38 3 40 3 38 3 38 3 42 4 46 3 35 :2 32 :2 45 4 37 3 39 3 35 3 37 3 40 3 40 4 39 4 43 3 39 4 43 3 40 3 36 3 37 4 40 8 37 3 40 6 o 0 35 4 48 5 o 0 34 4 31 5 o 0 35 2 39 5 35 3 Min. 1.0. (Ins.) 2.88 2.90 2.91 2.91 2.89 2.90 2.90 2.91 2.91 2.92 2.91 2.91 2.92 2.91 2.91 2.90 2.90 2.90 2.89 2.92 2.89 2.89 2.90 2.86 2.88 2.89 2.89 2.89 2.88 2.90 2.89 2.92 2.90 2.92 2.93 N/A 2.87 2.89 2.81 2.90 2.88 3.00 2.88 2.91 2.90 Well: Field: Company: Country: Survey Oate: 1 0-1 38 Kuparuk ConocoPhillips Alaska, Inc. USA August 18, 2005 Comments Corrosion. Corrosion. Lt Oeposits. Corrosion. Isolated pitting. Lt. Oeposits. Corrosion. Corrosion. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Corrosion. Lt. Deposits. Isolated pitting. Corrosion.. Corrosion.. Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion. Line of corrosion. Lt. Oeposits. Line of corrösion. Lt. Oeposits. Corrosion. Lt. Oeposits. Corrosion. Lt. Oeposits. Corrosion. Lt. Oeposits. Corrosion. Corrosion. Corrosion. Corrosion. Lt. Oeposits. PUP Corrosion. GLM 1 (Latch @ 2:00) PUP Corrosion. Lt. Oeposits. Corrosion. OS N jpple Corrosion. Lt. Deposits. PUP Isolated pitting. Lt. Oeposits. SEAL, Shallow pitting in Seal PUP Corrosion. Corrosion. Lt. Oeposits. Corrosion. Lt. Oeposits. Page 4 Oamage Profile (% wall) o 50 100 . Penetration Body ~ Metal Loss Body cId,-s - - ^-..} - ,-~- ·I~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 D- 13 8 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 18, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 89 at depth 2831.367 ft Tool speed = 54 NominallD = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 67 0 Finger 24 Penetration = 0.206 ins Corrosion 0.21 ins = 81% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cIds ...~L. _,_ __ ~ PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0- 13 8 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 18, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 91 at depth 2910.743 ft Tool speed = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation = 67 0 Finger 22 Penetration = 0.188 ins Corrosion 0.19 ins = 74% Wall Penetration HIGH SIDE = UP Cross Sections page 2 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Jun 28 14:51:42 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 00/06/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1D-138 500292295700 Arco Alaska, Sperry Sun 28-JUN-00 MWD RUN 3 MWD RUN 4 AK-MM-00023 AK-MM-00023 B. HENNINGSE B. HENNINGSE D. WESTER D. WESTER 23 liN 10E 646 602 .00 100.90 70.40 Inc. RECEIVED JUL 06 000 Alaska Oil & Gas Cons. Commission Anchorage MWD RUN 5 AK-MM-00023 B. HENNINGSE D. HIEM WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.875 13.375 110.0 7.875 7.875 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 3 - 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 KICKS OFF FROM WELL 1D-138 PBt AT 144'MD, 144'TVD. 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M. WERNER OF PHILLIPS ALASKA, INC. AND R KALISH OF SPERRY-SUN ON 05/02/00. MWD DATA IS CONSIDERED PDC. WELL 1D-138 PB1 REACHED A DEPTH OF 1280'MD/TVD, AND WILL NOT BE PRESENTED. 4. MWD RUNS 3 - 5 REPRESENT WELL 1D-138 WITH AN API#: 50-029-22957-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6543'MD, 4199'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. THE FOLLOWING CURVES REPRESENT EWR4 DATA PROCESSED WITH VERTICAL RESISTIVITY INVERSION (VRI) MODELING: VEXP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (EXTRA SHALLOW SPACING). VESP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (SHALLOW SPACING). VEMP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (MEDIUM SPACING). VEDP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (DEEP SPACING). MEXP = MODELED PHASE SHIFT-DERIVED RESISTIVTY (EXTRA SHALLOW SPACING). MESP = MODELED PHASE SHIFT-DERIVED RESISTIVTY (SHALLOW SPACING). MEMP = MODELED PHASE SHIFT-DERIVED RESISTIVTY SPACING). MEDP = MODELED PHASE SHIFT-DERIVED RESISTIVTY SPACING). (MEDIUM ( DEEP $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 96.5 6495.0 RPX 100.0 6502.0 RPS 100.0 6502.0 RPM 100.0 6502.0 RPD 100.0 6502.0 FET 110.0 6502.0 ROP 269.5 6542.5 VESP 5330.5 6330.0 MEMP 5330.5 6330.0 MESP 5330.5 6330.0 MEXP 5330.5 6330.0 VEXP 5330.5 6330.0 VEMP 5330.5 6330.0 VEDP 5330.5 6330.0 MEDP 5330.5 6330.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: - EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 97.0 2464.0 4 2464.0 5325.0 5 5325.0 6543.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical .log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Siz DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 VEXP MWD OHMM 4 1 68 VESP MWD OHMM 4 1 68 VEMP MWD OHMM 4 1 68 VEDP MWD OHMM 4 1 68 MEXP MWD OHMM 4 1 68 MESP MWD OHMM 4 1 68 MEMP MWD OHMM 4 1 68 MEDP MWD OHMM 4 1 68 e Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 56 15 60 16 Name Service Unit Min Max DEPT FT 96.5 6542.5 ROP MWD FT/H 0 2188.96 GR MWD API 13.37 133.87 RPX MWD OHMM 1.554 2000 RPS MWD OHMM 0.94 2000 RPM MWD OHMM 0.65 2000 RPD MWD OHMM 0.76 2000 FET MWD HOUR 0.0125 67.3343 VEXP MWD OHMM 1.22 186.916 VESP MWD OHMM 0.418 204.717 VEMP MWD OHMM 0.118 413.88 VEDP MWD OHMM 0.144 2000 MEXP MWD OHMM 2.278 108.046 MESP MWD OHMM 2.38 119.676 MEMP MWD OHMM 1.162 2000 MEDP MWD OHMM 0.675 2000 Mean Nsam 3319.5 12893 121.861 12547 66.4462 12798 25.4231 12805 50.1264 12805 77.626 12805 122.997 12805 1.13712 12785 16.1713 2000 17.3279 2000 17.4709 2000 20.1225 2000 15.177 2000 15.8862 2000 16.7463 2000 21.4103 2000 First Reading 96.5 269.5 96.5 100 100 100 100 110 5330.5 5330.5 5330.5 5330.5 5330.5 5330.5 5330.5 5330.5 Last Reading 6542.5 6542.5 6495 6502 6502 6502 6502 6502 6330 6330 6330 6330 6330 6330 6330 6330 First Reading For Entire File .......... 96.5 Last Reading For Entire File ........... 6542.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 96.5 2420.5 RPM 100.0 2427.5 RPD 100.0 2427.5 RPS 100.0 2427.5 RPX 100.0 2427.5 FET 110.0 2427.5 ROP 269.5 2463.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE.CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 21-APR-00 Insite 0.41 MEMORY 2464.0 1.5 59.0 TOOL NUMBER PBO1494GRV4 PBO1494GRV4 7.875 110.0 Water Based 9.40 230.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR FfWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 9.1 2000 5.0 Name Service Unit Min Max DEPT FT 96.5 2463.5 ROP MWD030 FT/H 0 2188.96 GR MWD030 API 15.83 133.87 RPX MWD030 OHMM 1.554 2000 RPS MWD030 OHMM 1.69 2000 RPM MWD030 OHMM 1.64 2000 RPD MWD030 OHMM 1.74 2000 FET MWD030 HOUR 0.0125 67.3343 1.400 1.029 1.100 1.800 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Mean Nsam 1280 4735 125.286 4389 65.61 4649 42.0294 4656 96.2687 4656 162.355 4656 268.225 4656 1.33701 4636 71.0 99.0 71.0 71.0 First Reading 96.5 269.5 96.5 100 100 100 100 110 Last Reading 2463.5 2463.5 2420.5 2427.5 2427.5 2427.5 2427.5 2427.5 First Reading For Entire File .......... 96.5 Last Reading For Entire File ........... 2463.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2421.0 5282.0 RPD 2428.0 5289.0 RPM 2428.0 5289.0 RPS 2428.0 5289.0 RPX 2428.0 5289.0 FET 2428.0 5289.0 ROP 2464.0 5325.0 $ # LOG HEADER DATA DATE LOGGED: 24-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 5324.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.0 MAXIMUM ANGLE: 67.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA TOOL NUMBER PBO1494GRV4 PBO1494GRV4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 7.875 110.0 Water Based 9.50 202.0 9.0 1800 4.8 2.000 1.532 1.900 2.100 75.0 100.0 75.O 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR Min Max Mean Nsam 2421 5325 3873 5809 0 322.67 133.005 5723 13.37 119.99 64.1141 5723 2.023 492.321 17.0902 5723 0.94 1931.49 27.9726 5723 0.65 2000 35.8188 5723 0.76 2000 50.9028 5723 0.1578 13.0161 0.863006 5723 First Reading 2421 2464 2421 2428 2428 2428 2428 2428 Last Reading 5325 5325 5282 5289 5289 5289 5289 5289 First Reading For Entire File .......... 2421 Last Reading For Entire File ........... 5325 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5282.5 6495.0 RPX 5289.5 6502.0 RPS 5289.5 6502.0 RPM 5289.5 6502.0 RPD 5289.5 6502.0 FET 5289.5 6502.0 ROP 5325.5 6542.5 $ LOG HEADER DATA DATE LOGGED: 26-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 6543.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.4 MAXIMUM ANGLE: 67.2 - # TOOL STRING (TOP TO.BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PBO1494GRV4 PBO1494GRV4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.875 110.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 10.00 252.0 9.4 1000 4.0 1.900 .000 1.800 2.200 74.0 106.7 74.0 74.0 Name Service Order Units Size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 5282.5 6542.5 5912.5 2521 First Reading 5282.5 Last Reading 6542.5 ROP MWD050 FT/H 0 241.22 GR MWD050 API 18.74 126.85 RPX MWD050 OHMM 2.339 103.669 RPS MWD050 OHMM 2.43 111.8 RPM MWD050 OHMM 2.42 97.96 RPD MWD050 OHMM 2.63 77.19 FET MWD050 HOUR 0.2576 20.9043 89.4977 2435 5325.5 6542.5 73.55 2426 5282.5 6495 13.2097 2426 5289.5 6502 13.8312 2426 5289.5 6502 13.6382 2426 5289.5 6502 14.3449 2426 5289.5 6502 1.40177 2426 5289.5 6502 First Reading For Entire File .......... 5282.5 Last Reading For Entire File ........... 6542.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 00/06/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
