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203-127
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-02 MILNE PT UNIT S-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/12/2023 S-02 50-029-23169-00-00 203-127-0 W SPT 4007 2031270 1500 881 883 882 884 444 522 524 524 4YRTST P Sully Sullivan 8/15/2023 Operator chose to pt to 2000psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT S-02 Inspection Date: Tubing OA Packer Depth 1298 2006 1967 1963IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230816133434 BBL Pumped:0.5 BBL Returned:0.5 Thursday, October 12, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg i'1-f!�'Ill P.I. Supervisor l ` FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 28, 2019 SUBJECT: Mechanical Integrity Tests Hilco p Alaska LLC S-02 MILNE PT UNIT S-02 Sre: Inspector Reviewed Bi -D P.I. Supry 5� Comm Well Name MILNE PT UNIT S-02 API Well Number 50-029-23169-00-00 Inspector Name: Brian Bixby Insp Num: mitBD6190805070715 Permit Number: 203-127-0 Inspection Date: 8/1/2019 " Rel Insp Num: Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min Tell ... s o2 ' Type Inj W TVD 4007 Tubing 721,s 7729 726 - 7? 2031270 TYPe Test sar Test psi Isoo - IA 0 1724 - 1637 — -- BBL Pumped: 1.4 BBL Returned: 1.2 OA l4 t49 - 51 - 49 Interval I 4YRTST p/F P Notes: Wednesday, August 28, 2019 Page I of I STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMOSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Acid Stimulation Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perf.New Pool ❑ Repair Well Q Re-enter Susp Well❑ CT Fill Clean-out ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑ Exploratory❑ 203-127 • 3.Address: Stratigraphic❑ Service ❑✓ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23169-00-00 ' 7.Property Designation(Lease Number): ,r 8.Well Name and Number: • ADL0380110 1 ADL0380109 MILNE PT UNIT SB S-02 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 6,235 ` feet Plugs measured N/A RECEIVED true vertical 4,586 • feet Junk measured 5,832 feet 5,516,5,681 & JAN 1 1 2016 Effective Depth measured 5,832 feet Packer measured 5,780 feet 4,008,4,136& AOGCC true vertical 4,257 feet true vertical 4,215 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,934' 9-5/8" 2,934' 2,438' 5,750psi 3,090psi Production 6,235' 7" 6,235' 4,586' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet SCORED MAY 0 2 2016 True Vertical depth See Attached Schematic feet SCORED Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/IBT 5,804' 4,234' 7"x 3.5"Premier TC-II 7"x 3.5"Premier TC-II Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"x 3.5 S-3 N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Development Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: • Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-694 Contact Stan Porhola Email sporhola(Cr�hilcorp.com Printed Name Bo York Title Operations Manager Signature " Phone 777-8345 Date 1/11/2016 Form 10-404 Revised 5/2015 /-/3-CA' RBDMS ,IAN 2 2016 Submit Original Only /36,6 • • Milne Point Unit .. Well: MP S-02 SCHEMATIC Last Completed: 8/11/2003 Hileoro Alaska,LLC PTD: 203-127 CASING DETAIL Orig.KB Elev.:72.13'/Orig.GL Elev.:38.30' Size Type Wt/Grade/Conn ID Top Btm j ,520" Conductor 94/L-80/N/A 19.124" Surface 112' 20 ' LI 9-5/8" Surface 40/L-80/Btrc. 8.835" Surface 2,934' t 7" Production 26/L-80/Btrc 6.875" Surface 6,235' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 5,804' "` JEWELRY DETAIL ,; 1 ,, No Depth Item t 1 2,196' 3.5"HES X-Nipple(2.813"Profile) 2 5,479' 3.5"Polish Bore Receptacle(54k shear,not sheared 9-5/8" . ,ie 3 5,505' 3.5"HES X-Nipple(2.813"Profile) 4 5,516' 7"x 3.5"Baker Premier Packer TC-II 5 5,542' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set • 6 5,611' 3.5"CAMCO MMM(1-1/2"RK Latch)Inj Valve to be set 7 5,670' 3.5"HES X-Nipple(2.813"Profile) 8 5,681' 7"x 3.5"Baker Premier Packer TC-II 9 5,707' 3.5"CAMCO MMG(1-1/2"RK Latch)Dummy Valve Set 10 5,744' 3.5"CAMCO MMG(1-1/2"RKP Latch)Inj Valve to be set 11 5,780' 7"x 4.5"x 3.5"Baker S-3 12 5,795' 3.5"RMX Sub(2.813"Profile;2.750 No Go)Inj Valve to be set 13 5,802' 3-1/2"WLEG 9-CR—Bottom @ 5,804' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'NB' 5,572' 5,603' 4,050' 4,074' 31 8/10/2003 Open 'OA' 5,734' 5,765' 4,178' 4,203' 31 8/102003 Open 5,800' 5,810' 4,231' 4,239' 10 8/10/2003 Open 'OB' 5,803' 5,832' 4,233' 4,257' 29 5/21/2006 Open 2 5,824' 5,831' 4,250' 4,256' 7 8/10/2003 Open IIICorrelated to SCMT 8/9/2003: 8/10/2003 Perforations—3-3/8",6SPF,60Deg.,PowerJet. w 3 5/21/2006 Perforations-2-1/2",5SPF,45 Deg.,Power Spiral(Strip Gun) __ a OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set(Approx.)in a 42"Hole 5 9-5/8" 70 sx PF'12,615 sx'E',225 sx'G'in a 12-1/4"Hole 7" 310 sx Class'G'in a 8-1/2" , 6 WELL INCLINATION DETAIL I KOP 10 deg.@ 754' li 7 Max Hole Angle=54 deg.@ 4,303' , 8 Hole Angle thru Perfs=35 deg. II e s / TREE&WELLHEAD y 4 OA Sands C Tree 4-1/16"- SM FMC 10 4 Wellhead 11"x 4.5"SM Gen 6 w/4.5"TC-IIT&B Tubing . iti, ca! • Hanger CIW"H"BPV Profile �'11 ;),,,,,P GENERAL WELL INFO API:50-029-23169-00-00 / Cased&Straddle Completed by Doyon 14 -8/11/2003 •'`12 Add Perforations—5/21/2006 13 1 r OB Sands TOF @5,837:2 1/7`4 J Strip Gun left in Hole 4. 5/21/2006-10'x 2-1/2'x1/8" '° i. sg 7" kiarra,,Wfil TD=6,235'(MD)/TD=4,586'(TVD) PBTD=6,150'(MD)/PBTD=4,516'(TVD) Revised By:STP 1/11/2016 • Hilcorp Alaska, LLC 0 Weekly Operations Summary Well Name /441 API Number Well Permit Number Start Date End Date MP S-02 ( CTU 50-029-23169-00-00 203-127 12/5/15 12/11/15 Daily Operations: 12/2/2015 -Wednesday No activity to report. 12/3/2015 -Thursday No activity to report. 12/4/2015 - Friday No activity to report. 12/5/2015-Saturday NU BOPs and Pump-in Sub, MU Injector Head, performed BOPE Test, Funtioned BOPs and Tested,Valve 250psi low- 4,500psi high, Rams 250-4500psi. NO failures recorded. Bled of Pressure to OT, RD Injector and MU BHA 2" Internal Dimple C.C., 2.13" DFCV, 2.13" WT Bar, 2.13" Hyd Disconnect (9/16" ball), 2.13" Jet Nozzle (side and down jets). Pulled test-good. MU Injector tested brake to 4,500psi, Pumped 5 bbls of 60/40 to freeze protect tank, broke circulation and swapped to 1% kcl at 1.7 bpm. At 10bbls pump pressured increased to 3,500psi at .9bpm. At 19bbls pumped increased and couldnt pump in CT. Bled off CT and Broke injector Head, LD Jet Nozzle and Disconnect. Stabbed back on well and still could not pump into CT. Ice plug in reel.Tarped reel and heated. Broke Injector off well, Secured Unit and SDFN Waiting on reel to thaw. 12/6/2015 -Sunday Hooked up 1/2" line to reverse cir. Pressure tested and pumped 1 bbl and esablished cir. SD pump. Stabbed Injector head on well and Waited for Little Red to bring 50bbls of neet. Continued heating Reel and circulating lines. MIRU Little Red,Test lines and circulated 48 bls of neet thru coil @ 1.7 bpm 2,600psi. Rolled 400 bbls with Little Red to 130 degs. PT 4,500, Circulated 60/40 out of CT with 130 deg 1% KCL to 50bbI OT. Opened well and RIH @ .5 bpm. Weight ck @ 5,300' 19,000Ibs.Tagged at 5,558' increased rate to 2bpm washed down to 5,598'. Returns freeze protect, KCL and traces of cement fines.At 5,599' tagged hard and could not wash through. POOH Freeze protecting at 2,500'. SI Well. Freeze protected CT, RU Injector Head, MU 2.25 Mill and 2-1/8" Motor. Secure Location and SDFN. 12/7/2015- Monday Held PJSM, SD to repair CT counter on Unit Time. Stabbed on Injector Head and PT 4,500psi-Test ok. RIH dry with 2.25" Mill and 2-1/8" Motor tagged 5,735', pumping 2bpm milled stringers down to top of RMX Prong @ 5,767' . Circulated Bottoms up. Returns Cleans with a trace of cement fines. SI Well and pumped away 10bbls @ .5bpm/1,340psi-(GOOD INJECTIVITY TEST). POOH Freeze Protected CT and surface lines. Bumped up Coil and SI well, RD Injector and LD Milling BHA. MU BHA 2" Internal Dimple C.C., 2.13" DFCV, 2.13" WT Bar, 2.13" Hyd Disconnect (9/16" ball), 2.13"Jet Nozzle (side and down jets). Unit maintenance. SDFN. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-02 CTU 50 029 23169 00 00 203 127 12/5/15 12/11/15 � a -,��F, 1 i Q�, 1, �� , Daily Operatitris. if, ,A 1,14,1 r ,,, 6 0 12/8/2015-Tuesday Held PJSM and discuss daily ops.Stab Injector Head and PT 4,500psi-Test Good. Circulated 44 bbls 60/40 out of the CT to 50bbls tank with 130 deg 1% KCL. Opened well and RIH w/Jet Nozzle. Washed across injection mandel @ 5,728' CTM and washed off prong at RMX sub @ 5,779' CTM and circulated 2 bottoms up, with returns clean POOH. SI well and RD Injector Head, LD Wash Nozzle. PU/MU 2-1/2" Otis RB Pulling Tool. MU Injector Head and PT to 4,500psi-Test Good. Broke circulation to OT and Opened well. RIH w/same to tag prong @ 5,779'. Latched POOH. Freeze protected well and CT. RD Injector Head did not latch Prong. Fishing Tool was full of cement. Discussed plans with Anchorage, plan on running a burn shoe over prong AM. • Hilcorp Alaska, LLC 4'44 Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP S-02 CTU 50-029-23169-00-00 203-127 12/5/15 12/11/15 Daily Operations: 12/9/2015-Wednesday HELD PJSM and discussed daily operations. Stab on Injector Head and PT to 4,500psi-Test Ok. Circulated 60/40 out of CT with hot 1% KCL to 50 bbl OT. RD Injector and MU 2-1/8"Jet Nozzle PT to 4,500psi-Test OK.-RIH w/same pumping .3bpm and tag RMX Sub @ 5,779'. Parked CT. HELD PJSM, MIRU Little Red and SLB Acid Transport. PT Lines to 4,500psi-Test OK. Pumped 5 bbls of 10% HCI Acid and displace with 1% KCL. Spotted acid on top of RMX Sub. SD pump and PUH to 3,700. Parked CT. Waited on Acid to dissolve Cement. RIH and tag RMX sub @ 2bpm, Circulated 65 bbls to OT(2 bottoms up) returns acid & clean fluid no solids. POOH. SD Pump. POOH. Bumped CT and SI well. Bled off to OT, RD Injector LD Jet Nozzle and PU/MU Drain Sub 2-1/2"JDC Pulling Tool. Stab Injector on well PT to 4,500psi-Test ok. Opened well RIH and tag 5,780'. Made 5 attemps to latch prong. POOH. RD Injector Pulling tool skirt was full of cement. LD Pulling tool MU/PU 2- 1/8" Motor and 2-5/8" Burn Shoe. Stab on Injector PT 4,500psi-Test Ok. Open well and RIH Tag 5,781'. Rolled Pump over 1.5bpm milled down to 5,784'. PU out of stall washed back down tag 5,784' and stalled same spot, made one more attempt with the same result. PU 5' and circulated bottoms up. POOH. Freeze protected well and CT. Closed Well and RD Injector Head. L/D Motor and Burn Shoe. Tattletale in Shoe showed impression of the fish neck on top of the prong. PU/MU Pulling tool. Secure Unit and SDFN. 12/10/2015 -Thursday Held PJSA. Stab Injector on Well, PT 4,500psi-Test Ok. Opened well and RIH w/2-1/2"JDC Pulling Tool and tag 5,781'. Latched Prong pulled 2k over and released prong. POOH. Bump up and SI well. RD Injector LD Prong and JDC Pulling tool. MU Jet Nozzle stab Injector on Well, Circulated freeze protect to 50bbI OT with Hot 1% KCL. Open Well and RIH tagged at 5,784'Washed down pumpimg 2bpm to 5,787' (HARD TAG RMX SUB). Circulate 2 Bottoms Up with 1% KCL and POOH. Freeze Protected well and CT. Bumped up and SI well. Blow down lines and RD Injector Head, LD BHA installed Night CAP secured Unit and SDFN. 12/11/2015- Friday Held PJSM. RDMO SLB CTU 4 and associated equipment. 12/12/2015-Saturday No activity to report. 12/13/2015-Sunday No activity to report. 12/14/2015 - Monday No activity to report. 12/15/2015 -Tuesday No activity to report. •L OF ��F • • �w��\\I%%/�s� THE STATE Alaska Oil and Gas N�►r'' ��� ofASKA. Conservation Commission ��a s►re 7i" � z=-- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `4',16:210` Q, Main: 907.279.1433 ALAS'` Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED FEB 0 2 2016 Bo York Operations Manager Hilcorp Alaska, LLC a03- /a3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-02 Sundry Number: 315-694 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /a4-4-441---- Cathy P. Foerster Chair DATED this�ay of November, 2015 Encl. RBDMS 1. tCC04MS • • RECEIV STATE OF ALASKA NOV 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ 14'-0`'Other Stimulate ❑2 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other.CT Fill Clean-out ❑, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑ 203-127 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑. 6.API Number. Anchorage,AK,99503 50-029-23169-00-00 . 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 2 MILNE PT UNIT SB SO2- - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380110 I ADL0380109 _ MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): 3300 Plugs(MD): Junk(MD): 6,235' • 4,586' • 5,832' 4,257' �v N/A 5,832' Casing Length Size MD TVD it Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,934' 9-5/8" 2,934' 2,438' 5,750psi 3,090psi Production 6,235' 7" 6,235' 4,586' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic ' See Attached Schematic 3-1/2" 9.2#/L-80/IBT 5,804 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): (2)-7"x 3.5 Baker Premier&7"x 4.5"x 3.5"Baker S-3 and N/A , 5,780'/4,008',5,681'/4,136'&5,780'/4,215'and N/A 12.Attachments: Proposal Summary E Wellbore schematic El 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: CommencingOperations: 11/20/2015 p OIL El WINJ E - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email sporhola a(hilcorp.com Printed Name Bo York Title Operations Manager r Signature/9"------ Phone 777-8345 Date ��� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 7' 31 6- Co9q Plug Integrity ❑ BOP Test M Mechanical Integrity Test ❑ Location Clearance El JE Other: l(Si)e) 75, 6'(:-)I)`' f� ' ) z-S f-( C Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS�� C u 4 L�15 Spacing Exception Required? Yes ❑ No 71/ Subsequent Form Required: ic, `-/cy.4 APPROVED BY Approved by:0...../ f Y-� COMMISSIONER THE COMMISSION Date: /1—ZS- / s--- - / cam(, (\� \\- \\'-? \ K/12.�I S it 2 315— orm 10 OROleGliN3Allid (��t1~— Submit Form and Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate • Well Prognosis Well: MPU S-02 nakor„Alaska,LI) Date: 11/06/2015 Well Name: MPU S-02 API Number: 50-029-23169-00 Current Status: SI Water Injector Pad: Milne Point S-Pad Estimated Start Date: November 20th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-127 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1552429 Current Bottom Hole Pressure: 2,454 psi @ 4,000' TVD (Last BHP measured 8/23/2012) Maximum Expected BHP: 2,454 psi @ 4,000' TVD (No new perfs being added) Max. Anticipated Surf Pressure: 694 psi (Based on SBHP taken 8/23/2012 and water cut of 100% (0.440psi/ft)) Max. Predicted Surf Pressure: 2,054 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: 74 z MPU S-02 was drilled with Doyon #14 in 2003 as a deviated injector in the Schrader Bluff NB, OA and OB sands and provides support in hydraulic unit 15 for offset producers MPU S-12. The well has had several MBE treatments that have been treated with some limited success. An MBE treatment in September 2015 was performed that got both the first and second treatments pumped away. However, an injectivity test after the second treatment failed and slickline was unable to reach the desired depth due to unset cement in the tubing. Notes Regarding Wellbore Condition • Well is a deviated water injector(max angle 54° @ 4,303'). • Shut-in water injection with a failed MBE (Matrix Bypass Event)treatment with cement at 5,655' SLM. Objective: The purpose of this work is to remove the unset cement from inside the tubing and re-establish communication thru the waterflood mandrel (at 5,744' MD) into the OA sands., Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.4 ppg 1% KCI. 2. Pressure test BOPE to 4,500 psi Hi 250 Low. 3. RIH w/2.00" coil w/2-1/8" wash nozzle to +/- 5,500' MD. Circulate well w/8.4 ppg 1% KCI. V 4. Continue to RIH and attempt to cleanout cement from+/-5,655' to +/-5,795.'..MD. 5. RU to test injectivity thru the mandrel into the OA sand. Do not exceed 3,500psi. POOH 6. Contingency: (If unable to cleanout cement w/wash nozzle.) a. RIH w/2.25" OD mill, 2-1/8" motor, and oil jars and cleanout cement to+/- 5,795' MD. b. RU to test injectivity thru the mandrel into the OA sand. Do not exceed 3,500 psi. POOH 7. Contingency: (If able to cleanout cement but unable to establish injectivity.) • • Well Prognosis Well: MPU S-02 Hilcorp Alaska,LLt Date: 11/06/2015 a. RIH w/2-1/8" wash nozzle to+/-5,744' MD. 1.: b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 4,000 psi. • c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.4 ppg 1% KCI. POOH. d. RD acid pumin unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.4 ppg 1% KCI. g. RU to test injectivity thru the mandrel into the OA sand. Do not exceed 3,500 psi. POOH. h. Contingency: (If unable to establish injectivity test after HCI soak, repeatStep#7 [a-g]). 8. RIH w/2-1/2" wash nozzle to+/- 5,795' MD (above plug in RMX sub). 9. Cleanout above plug in RMX sub. Circulate well w/8.4 ppg 1% KCI. POOH. P 10. MU 2-1/2" Otis RB pulling tool. 11. RIH w/pulling tool and recover prong from RMX plug at 5,795' MD. POOH. 12. RD Coiled Tubing and ancillary equipment. 13. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coil BOPE Schematic H . 0 Milne Point Unit Well: MPS-2 SCHEMATIC Last Completed: 8/11/2003 Hilcorp Alaska,LLC PTD: 203-127 CASING DETAIL Orig.yyyKB Elev.:72.13'/Orig.GL Elev.:38.30' Size Type Wt/Grade/Conn ID Top Btm :1 IL,, 20" Conductor 94/L-80/N/A 19.124" Surface 112' 20" l• 9-5/8" Surface 40/L-80/Btrc. 8.835" Surface 2,934' yi 7" Production 26/L-80/Btrc TUBING DETAIL 6.875" Surface 6,235' ." Kti 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 5,804' JEWELRY DETAIL le, I 1 No Depth Item cfi -1, 1 2,196' 3.5"HES X-Nipple(2.813"Profile) 0, 2 2 5,479' 3.5"Polish Bore Receptacle(54k shear,not sheared 95/8 &� 3 5,505' 3.5"HES X-Nipple(2.813"Profile) 4 5,516' 7"x 3.5"Baker Premier Packer TC-II 5 5,542' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set 6 5,611' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set 9/12/15 7 5,670' 3.5"HES X-Nipple(2.813"Profile) 8 5,681' 7"x 3.5"Baker Premier Packer TC-II 9 5,707' 3.5"CAMCO MMG(1-1/2"RK Latch)Dummy Valve Set 10 5,744' 3.5"CAMCO MMG(1-1/2"RKP Latch)Open Pocket 9/12/15 11 5,780' 7"x 4.5"x 3.5"Baker S-3 12 5,795' 3.5"RMX Sub(2.813"Profile;2.750 No Go)Dummy Prong Set 9/12/15 13 5,802' 3-1/2"WLEG 9-CR—Bottom @ 5,804' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 'NB' 5,572' 5,603' 4,050' 4,074' 31 8/10/2003 Open 'OA' 5,734' 5,765' 4,178' 4,203' 31 8/102003 Open 5,800' 5,810' 4,231' 4,239' 10 8/10/2003 Open 'OB' 5,803' 5,832' 4,233' 4,257' 29 5/21/2006 Open 2 5,824' 5,831' 4,250' 4,256' 7 8/10/2003 Open Correlated to SCMT 8/9/2003: 8/10/2003 Perforations—3-3/8",6SPF,6ODeg.,Power-Jet. 4 3 ` 5/21/2006 Perforations—2-1/2",5SPF,45 Deg.,Power Spiral(Strip Gun) 4 OPEN HOLE/CEMENT DETAIL 'i 15 20" 260 sx Arctic Set(Approx.)in a 42"Hole *W 9 5/8" 70 sx PF'L',615 sx'E',225 sx'G'in a 12-1/4"Hole ;: 7" 310 sx Class'G'in a 8-1/2" Unset Cement @ 6 }NB Sands civ c WELL INCLINATION DETAIL T�2 * �C'µ� l KOP 10 deg.@ 754' 7 ( {A LLi, Max Hole Angle=54 deg.@ 4,303' A 8 4' ' Hole Angle thru Perfs=35 deg. 49 TREE&WELLHEAD 1 47-CIA Sands Tree 4-1/16"- 5M FMC 4,: 10Wellhead 11"x 4.5"5M Gen 6 w/4.5"TC-II T&B Tubing , i? Hanger CIW"H"BPV Profile ii , 11 H aw; GENERAL WELL INFO ,' 1 1. 411'1" API:50-029-23169-00-00 12 A �� Cased&Straddle Completed by Doyon 14 -8/11/2003 Add Perforations—5/21/2006 ,A }13 CB Sands TOF @ 5,837:2-1/21 Strip Gin left in Hole 1$1 5"21/2006-1a x "s; R✓ 2-1/2 x 1/8 1t y 7 10+: ' TD=6,235'(MD)/TD=4,586'(1VD) PBTD=6,150'(MD)/PBTD=4,516'(TVD) Revised By:STP 11/06/2015 • H . Well: MPS-2 Milne Point Unit • PROPOSED SCHEMATIC Last Completed: Proposed Mean)Alaska,LLC PTD: 203-127 CASING DETAIL Orig.KB Elev.:72.13'/Orig.GL Elev.:38.30' Size Type Wt/Grade/Conn ID Top Btm d 20" Conductor 94/L-80/N/A 19.124" Surface 112' 2(y'a , rt 9-5/8" Surface 40/L-80/Btrc. 8.835" Surface 2,934' IP 7" Production 26/L-80/Btrc 6.875" Surface 6,235' *0, * TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 5,804' JEWELRY DETAIL 1 No Depth Item 1 2,196' 3.5"HES X-Nipple(2.813"Profile) 2 5,479' 3.5"Polish Bore Receptacle(54k shear,not sheared 9-5/8" • 1 3 5,505' 3.5"HES X-Nipple(2.813"Profile) 4 5,516' 7"x 3.5"Baker Premier Packer TC-Il 5 5,542' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set 6 5,611' 3.5"CAMCO MMM(1-1/2"RK Latch)Inj Valve to be set 7 5,670' 3.5"HES X-Nipple(2.813"Profile) 8 5,681' 7"x 3.5"Baker Premier Packer TC-II 9 5,707' 3.5"CAMCO MMG(1-1/2"RK Latch)Dummy Valve Set 10 5,744' 3.5"CAMCO MMG(1-1/2"RKP Latch)Inj Valve to be set 11 5,780' 7"x 4.5"x 3.5"Baker S-3 12 5,795' 3.5"RMX Sub(2.813"Profile;2.750 No Go)Inj Valve to be set 13 5,802' 3-1/2"WLEG 9-CR–Bottom @ 5,804' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 'NB' 5,572' 5,603' 4,050' 4,074' 31 8/10/2003 Open 'OA' 5,734' 5,765' 4,178' 4,203' 31 8/102003 Open 5,800' 5,810' 4,231' 4,239' 10 8/10/2003 Open 'OB' 5,803' 5,832' 4,233' 4,257' 29 5/21/2006 Open 2 5,824' 5,831' 4,250' 4,256' 7 8/10/2003 Open Correlated to SCMT 8/9/2003: 8/10/2003 Perforations–3-3/8",6SPF,6ODeg.,Poweriet. 3 5/21/2006 Perforations–2-1/2",SSPF,45 Deg.,Power Spiral(Strip Gun) 4 OPEN HOLE/CEMENT DETAIL '` III 20" 260 sx Arctic Set(Approx.)in a 42"Hole A 5 9-5/8" 'L 70 sx PF ' 615 sx'E' 225 sx'G'in a 12-1 4"Hole 4, / 7" 310 sx Class'G'in a 8'1/2" s} NB Sands WELL INCLINATION DETAIL KOP 10 deg.@ 754' a 7 Max Hole Angle=54 deg.@ 4,303' 9A ' '._, ,;8 Hole Angle thru Perfs=35 deg. '?, II �. 9 TREE&WELLHEAD - =3 OA Sands Tree 4-1/16"- 5M FMC 10 . 11"x 4.5"5M Gen 6 w/4.5"TC-II T&B Tubing ;' I Wellhead Hanger CIW"H"BPV Profile }4 1 GENERAL WELL INFO 4., ' 1 API:50-029-23169-00-00 '7 ', Cased&Straddle Completed by Doyon 14 -8/11/2003 ,40 —12 ', Add Perforations–5/21/2006 f*, 13 CB Sands TOF @5,832:2-1121 Strip Gin left in Hole 5/21/2006-10 x "'A 2-1/2 x 1/8 v 7" t-ti fAr e TD=6,235'(MD)/TD=4,586'(1VD) PBTD=6,150'WO)/PBTD=4,516'(WD) Revised By:STP 11/06/2015 • • • II Milne Point Unit COIL BOPE MPU S-02 rii�.rl. \L. . 11 i,� 10/08/2015 MPU S-02 20 X9% X7X3%: Coil Tubing BOP Lubricator to injection head 2.00"Single Stripper 1 0I1 Blind/Shea r=" 1/16 10 = 1 Blind/Shear ,I,'• 111)0111 _� 111 Blind/Shear-= =-Blind/Shear 111,1• k = limn- ----- Slip El. Slip All 111 ��li __� i •',I,I_ IIM Pipe •I,'•V •. 1i mo øi Crossover spool 4 1/16 10M X 4 1/16 5M e Pump-In Sub ,« I 61 4 1/16 5M . ' ; I• ,�`' I1..1, 1502 Union ell n . � j Manual Gate Manual Gate Valve,Swab,WKM-M, 2 118 5M 2 1/8 5M or • 4 1/16 5M FE • °- \(0. kW.MI INS MI �•c'Qd g�` Valve, Upper Master,Baker, 4 1/16 5M FE,w/HydraulicIF Valve,Lower Master,WKM-M, � . • 4 1/16 5M FE �y iIii Tubing Adapter,4 1/16 5M • • • w tp 0. 0.a R J + L R O m N N v c c e U a U A o v a � z aocz = > m a° 4, UwiJ: Q ° m aim (I_, o lgzzo » om 4) p a � v74 s E > > c. DO0 ( E a o > d r C7 'n > v i 3 0' a w > 0 a' v a 7 jKJ 9 w r c 2 O L • A C7 ,: mai*ow— , a p tP13QV o.T 6 ,� IIII III in IIII R.17- l- it 'III maIII,II a 1 .ILII{a 1:._ ,' I 1111 1111 1111 1111 T OOH p 0 p NZ Wa W iiii O 0 0 0 In ~t5: it' 0 C C. V Y Z a H J J Y fJL [11 8 • • i I— x 1— o x E ID 0. E m E oi _. 11 tt en co co • • , -0 g 8 .::,-.• 8 •:: :: -. :: -. c. ,, ,_..,=' ,.= 43.1 •.. :::.. : p.,__f _ IL LLI V1 VI —4403--- 411XZZO z : . .: -.. S. 0 a. b _ • .. r*** t.L .6 u > '`p," ..e . . .: :: 3 •,- 4, ..12,„ ....• =8 ,..E o. • • ri.,.. ir ,••• ._, E-.. > c.. a,...) a. a 0 ; iiii 41 'E n1 2 ; a) ,e 7 ' 5° i A. ,, •••.-41 ! ....,, i MI Dal : falig-t°1-1>— ,' ad ••4 • 4 10414 V d ° = 74 t Z: 2 ,, 0 'N'IN 111k 7 I- -.....-,. OUPP i. . ' MI Mil Mil In o ._-_-_. . 7 — __,1 111.11.11i. 'YISOI iii 4, . . (,__I 1111 1111 1111 in <4 BROD 0E- i i .. i i i i NI Z i .. .. .. .. 1.1J < cc ra. o o o o co Uj CD 0 0 c[ ui 0. V Y Z 4 I— d 2 LA_1 co co 8 MI::: same STATE OF ALASKA 0 5 2015 AL OIL AND GAS CONSERVATION COMMISSION ION REPORT OF SUNDRY WELL OPERATIONS AOG CC 1.Operations Abandon L] Plug Perforations L1 Fracture Stimulate U Pull Tubing Lf Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: MBE Treatment Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development❑ Exploratory ❑ 203-127 ' 3.Address: Stratigraphic Eli Service ❑l 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23169-00-00 7.Property Designation(Lease Number): . 8.Well Name and Number: ADL0380110 I ADL0380109 MILNE PT UNIT SB S-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 6,235 feet Plugs measured N/A feet true vertical 4,586 • feet Junk measured 5,832 feet 5,516,5,681 & Effective Depth measured 5,832 feet Packer measured 5,780 feet 4,008,4,136& true vertical 4,257 feet true vertical 4,215 feet Casing Length Size MD TVD •.-• Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,934' 9-5/8" 2,934' 2,438' 5,750psi 3,090psi Production 6,235' 7" 6,235' 4,586' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet CAN OEL., 1 5 19..„ni.J True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/IBT 5,804' 4,234' 7"x 3.5"Premier TFC-II 7"x 3.5"Premier TFC-II Packers and SSSV(type,measured and true vertical depth) 7"x 4.5"x 3.5 S-3 N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 200 Subsequent to operation: 0 0 0 0 20 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory El Development Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Stan Porhola Email sporholata7hilcorp.com Printed Name Stan PorholaTitle Operations Engineer Signature ...*--p Phone 777-8412 Date 10/5/2015 / �.t) 61i.(/ ' �/� (o A ( O/y15 Form 10-404 Revised 5/2015 � RBDMS 3 -'fief - 7 2015 Submit Original Only .. 14 • 0 Milne Point Unit Well: MP S-2 SCHEMATIC Last Completed: 8/11/2003 tlihor„Ala.ka,t.LC PTD: 203-127 CASING DETAIL Orig.KB Elev.:72.13'/Orig.GL Elev.:38.30' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 94/L-80/N/A 19.124" Surface 112' 20'-� 9-5/8" Surface 40/L-80/Btrc. 8.835" Surface 2,934' 7" Production 26/L-80/Btrc 6.875" Surface 6,235' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 5,804' JEWELRY DETAIL 1 No Depth Item 1 2,196' 3.5"HES X-Nipple(2.813"Profile) 2 5,479' 3.5"Polish Bore Receptacle(54k shear,not sheared 9-5/8" A k 3 5,505' 3.5"HES X-Nipple(2.813"Profile) 4 5,516' 7"x 3.5"Baker Premier Packer TC-Il 5 5,542' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set 6 5,611' 3.5"CAMCO MMM(1-1/2"RK Latch)Dummy Valve Set 9/12/15 7 5,670' 3.5"HES X-Nipple(2.813"Profile) 8 5,681' 7"x 3.5"Baker Premier Packer TC-Il 9 5,707' 3.5"CAMCO MMG(1-1/2"RK Latch)Dummy Valve Set 10 5,744' 3.5"CAMCO MMG(1-1/2"RKP Latch)open Pocket 9/12/15 11 5,780' 7"x 4.5"x 3.5"Baker S-3 12 5,795' 3.5"RMX Sub(2.813"Profile;2.750 No Go)Dummy Prong Set 9/12/15 13 5,802' 3-1/2"WLEG 9-CR—Bottom @ 5,804' PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'NB' 5,572' 5,603' 4,050' 4,074' 31 8/10/2003 Open 'OA' 5,734' 5,765' 4,178' 4,203' 31 8/102003 Open 5,800' 5,810' 4,231' 4,239' 10 8/10/2003 Open 'OB' 5,803' 5,832' 4,233' 4,257' 29 5/21/2006 Open 2 5,824' 5,831' 4,250' 4,256' 7 8/10/2003 Open Correlated to SCMT 8/9/2003: 8/10/2003 Perforations—3-3/8",6SPF,60Deg.,Poweriet. 3 5/21/2006 Perforations—2-1/2",5SPF,45 Deg.,Power Spiral(Strip Gun) ,�l�: 4 A_ ., OPEN HOLE/CEMENT DETAIL 20" 260 sx Arctic Set(Approx.)in a 42"Hole 5 9-5/8' 70 sx PF'L',615 sx'E',225 sx'G'in a 12-1/4"Hole 7" 310 sx Class'G'in a 8-1/2" Unset Cement @ 1: 6=3-NB sands WELL INCLINATION DETAIL 5'655 SlN1 Tag 9/24/15 s KOP 10 deg.@ 754' i 7 Max Hole Angle=54 deg.@ 4,303' 7--i< 8 Hole Angle thru Perfs=35 deg &WELLHEAD i'ili 5. =-J.-OA Sands Tree 4-1/16"- 5M FMC {t£?f+i 10 11"x 4.5"5M Gen 6 w 4.5"TC-II T&B Tubing Id / Wellhead �iitw`;. Hanger CIW"H"BPV Profile :,,�, . GENERAL WELL INFO liiililf API:50-029-23169-00-00 IN Cased&Straddle Completed by Doyon 14 -8/11/2003 12 Add Perforations-5/21/2006 s _ 13 TOF@5,832:2-1/2" + .= OB Sands Strip Gun left in Hole 5/21/2016-10'x " 2-1/2'x 1/8 TD=6,235'(MD)/TD=4,586'(TVD) PBTD=6,150'(MD)/PBTD=4,516'(TVD) Revised By:STP 10/5/2015 • Hilcorp Alaska, LLC iiit,.,,,.,> LIA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP S-02 50-029-231690-00-00 203-127 9/16/2015 9/22/2015 Daily Operations: 9/16/15-Wednesday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 1,500 psi-test OK. Perform injectivity test at 2.0 bpm @ 900 psi. Mix and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement,and 5 bbl of HEC. Drop foam ball. Displace w/27.0 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 21 bbl of diesel.SD Pumps. Monitor well. Final SITP of 1,200 psi. RDMO Cement Pump Unit&Little Red Pump Unit.SDFN. 9/17/15-Thursday No operations to report. 9/18/15-Friday No operations to report. 9/19/15-Saturday MIRU Cement Pump Unit& Little Red Pump Unit. PT lines to 4,200 psi -test OK. Perform injectivity test. Pressure up to 3,600 psi before breaking over. Establish injectivity at 0.9 bpm @ 1,300 psi.;Mix and pump Sbbl of HEC, 10 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/27.0 bbl of 1% KCI water.Switch to Little Red Pump Unit and pump 21 bbl of diesel.SD Pumps. Monitor well. Final SITP of 1,215 psi. RDMO Cement Pump Unit& Little Red Pump Unit.SDFN. 9/20/15-Sunday No operations to report. 9/21/15-Monday No operations to report. 9/22/15-Tuesday No operations to report. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Wednesday,September 02,2015 P.I.Supervisor 7(416-- SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-02 FROM: Bob Noble MILNE PT UNIT SB S-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J73/2— NON-CONFIDENTIAL 732NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-02 API Well Number 50-029-23169-00-00 Inspector Name: Bob Noble Permit Number: 203-127-0 Inspection Date: 8/31/2015 Insp Num: mitRCN150831164330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-02 ' IType Inj W-TVD 4007 TTubing 922 - 1 925 920 - 922 • PTD 2031270 Type Test SPT Test psi 1500 - IA 293 1 1813 • 1730 • 1711 Interval 4YRTST PAF P " OA 45 215 • 213 216 Notes: SCANNED Wednesday,September 02,2015 Page 1 of 1 OF Tit • 4„4,/'‘'\ �9 THE STATE Alaska Oil and Gas ofAT /k SIKA Conservation Commission li - z__= 333 West Seventh Avenue 10.1 \TM1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OFALAS� Fax 907 276 7542 www aogcc alaska.gov Stan Porhola Operations Engineer a03 - I a Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Pool, MPU SB S-02 Sundry Number: 315-460 SCANNED , - Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ae47 Cathy P. Foerster Chair DATED this 3t day of July, 2015 Encl. RECE I V E D STATE OF ALASKA i U L 2 $ L015 ALASKA OIL AND GAS CONSERVATION COMMISSION 7/30 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other. MBE Treatment ❑✓ 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development ❑ 203-127 - 3.Address: Stratigraphic ❑ Service 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23169-00-00 • 7 If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ ✓ MILNE PT UNIT SB S-02 ` 9.Property Designation(Lease Number): 10 Field/Pool(s): ADL0380110 I ADL0380109• MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured) Junk(measured) 6,235 - 4,586 - 5,832 . 4,257 . N/A 5,832' Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,934' 9-5/8" 2,934' 2,438' 5,750psi 3,090psi Production 6,235' 7" 6,235' 4,586' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic' See Attached Schematic 3-1/2" 9.2#/L-80/IBT 5,804 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): ��1 (2)-7"x 3.5 Baker Premier&7"x 4.5"x 3.5"Baker S-3 and N/A 44 ,-1 80L'(e/4,008',5,681'/4,136'&5,780'/4,215'and N/A 12.Attachments. Description Summary of Proposal Q 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. 8/11/2015 Commencing Operations: OIL ❑ WINJ Q• WDSPL ❑ Suspended El 16.Verbal Approval. Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporholatu�hilcorp.com Printed Name Stan Porhola Title Operations Engineer A1- Signature o'' ----- Phone 777-8412 Date 7/28/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 — `( (4o Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: ID—L/Q'-ti APPROVED BY r Approved by: - f' COMMISSIONER THE COMMISSION Date: 7 ., ,/S - 17/ -ZY•(S / '?1A3 /2q�/S RBDMA AUG - 1 1015 ,�vI �P IICat'dh'f �a71er,4 ?7 t� Submit Form and Form 10-403 Revised 5/2015 p r d p 1 s for 12 months from the date of approval. Attachments in Duplicate II Well Prognosis Well: MPU S-02 Ililwrp Alaska,LLI Date:7/28/2015 Well Name: MPU S-02 API Number: 50-029-23169-00 Current Status: SI Water Injector Pad: Milne Point S-Pad Estimated Start Date: August 11th, 2015 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-127 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 2,454 psi @ 4,000' TVD (Last BHP measured 8/23/2012) Maximum Expected BHP: 2,454 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 694 psi (Based on SBHP taken 8/23/2012 and water cut of 100% (0.440psi/ft)) Brief Well Summary: MPU S-02 was drilled with Doyon #14 in 2003 as a deviated injector in the Schrader Bluff NB, OA and OB sands and provides support in hydraulic unit 15 for offset producers MPU S-12. The well has had several MBE treatments that have been treated with some limited success. Notes Regarding Wellbore Condition • Well is a deviated water injector(max angle 54° @ 4,303'). • Shut-in water injection due to recent MBE (Matrix Bypass Event). • Assumed MBE between MPU S-02 and MPU S-12 (Jet Pump Oil Producer) based on increased water cuts in the producer, coming from water injection into the OA sands. Objective: The purpose of this work/sundry is to pump a MBE treatment and place well back on water injection./ Brief Procedure: Wireline Procedure 1. MIRU Slickline, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH and pull live gaslift valve from RMX sub @ 5,795'. 3. RIH and make drift run down to 6,150' (max deviation 54°, min ID=2.75"). 4. RIH and set dummy valve in RMX sub @ 5,795'./ 5. RIH and pull live gaslift valve from DV mandrel @ 5,707'. 6. RIH and set dummy valve in DV mandrel @ 5,707'. 7. RIH and pull live gaslift valve from DV mandrel @ 5,611'. 8. RIH and set dummy valve in DV mandrel @ 5,611'. 9. RIH and pull live gaslift valve from DV mandrel @ 5,542'. 10. RIH and set dummy valve in DV mandrel @ 5,542'. 11. RIH and confirm empty pocket in DV mandrel @ 5,744' (OA sands open). 12. RD Slickline. Pumping Procedure: Well Prognosis Well: MPU S-02 Hilcorp Alaska,LLQ Date:7/28/2015 13. Production to SI offset producers up to 5 days prior to treatment. 14. Production to SI offset injectors up to 2 days prior to treatment. 15. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#1] 16. Perform injectivity test w/8.4 ppg lease water at rates from 0.25-3.0 bpm. a. Do not exceed 1,250 psi for injectivity test. 17. Mix and bullhead the fo II o ing fluids: a. 10 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. 15 bbl of 15.8 ppg acid soluble cement. c. 5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. e. ( 0 bbl of 1% KCL water. f. 22.4 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 18. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 19. RDMO Cement Pumping Unit. 20. WOC 48 hours. 21. MIRU Hot Oil Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#1] 22. Mix and bullhead the following fluids: a. 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. 35+bbl of 8.4 ppg lease water or until injection rate stabilizes(same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure,do not exceed 3,600 psi. d. 20 bbl of 50/50 McOH/Water(freeze protection; after stable injection achieved). 23. RDMO Hot Oil Unit. • 24. MIRU Cement Pumping Unit. PT lines to 4,000 psi. [TREATMENT#2] 25. Fluid-pack and maintain tubing pressure on offset well affected by MBE (MPU S-12). 26. Mix and bullhead the following fluids: a. 10 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. 15 bbl of 15.8 ppg acid soluble cement. , 4,- 1^ ( ' c. 5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. � wb� d. Drop foam ball. 0c '7: 1, e. (30 bbl of 1% KCL water. Sid" 0.1 o� f. 22.4 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 27. Discontinue maintaining tubing pressure on offset well affected by MBE (MPU S-12). 28. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 29. RDMO Cement Pumping Unit. 30. WOC 48 hours. 31. MIRU Hot Oil Unit. PT lines to 4,000 psi. [INJECTIVITY TEST#2] 32. Mix and bullhead the following fluids: a. 5 bbl of 60/40 McOH/Water(to ensure injectivity). b. 35+ bbl of 8.4 ppg lease water or until injection rate stabilizes(same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 3,600 psi. d. 20 bbl of 50/50 McOH/Water(freeze protection; after stable injection achieved). 33. RDMO Hot Oil Unit. 34. Turn well over to production. II Well Prognosis Well: MPU S-02 lli!cora Alaska,LI) Date:7/28/2015 Attachments: 1. As-built Schematic 14Milne Point Unit Well: MP S-2 SCHEMATIC Last Completed: 8/11/2003 Ililcorp Alaska,LLC PTD: 203-127 CASING DETAIL Orig.KB Elev.:72.13'/Orig.GL Elev.:38.30' Size Type Wt/Grade/Conn ID Top Btm k 20" Conductor 94/L-80/N/A 19.124" Surface 112'2t7# T++ 9-5/8" , Surface 40/L-80/Btrc. 8.835" Surface . 2,934' 7" Production 26/L-80/Btrc 6.875" Surface 6,235' l". II r TUBING DETAIL u: 3-1/2" Tubing 9.2/L-80/IBT 2.992" Surf 5,804' 's' JEWELRY DETAIL „ 14 No Depth Item il 1 2,196' 3.5"HES X-Nipple(2.813"Profile) st, F4 2 5,479' 3.5"Polish Bore Receptacle(54k shear,not sheared 9-5/8' ' 3 5,505' 3.5"HES X-Nipple(2.813"Profile) _ 4 5,516' 7"x 3.5"Baker Premier Packer TC-II 5 5,542' 3.5"CAMCO MMM(1-1/2"RK Latch) ors _6 5,611' 3.5"CAMCO MMM(1-1/2"RK Latch) 7 5,670' 3.5"HES X-Nipple(2.813"Profile) 8 5,681' 7"x 3.5"Baker Premier Packer TC-II 9 5,707' 3.5"CAMCO MMG(1-1/2"RK Latch) O R C7 10 5,744' 3.5"CAMCO MMG(1-1/2"RKP Latch) 11 5,780' 7"x 3.5"Baker Premier Packer TC-II _12 5,795' 3.5"RMX Sub(2.813"Profile;2.750 No Go) 13 5,802' 3-1/2"WLEG 9-CR—Bottom @ 5,804' PERFORATION DETAIL ✓ Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'NB' _ 5,572' 5,603' 4,050' 4,074' 31 8/10/2003 Open 'OA' 5,734' 5,765' 4,178' 4,203' 31 8/102003 Open 5,800' 5,810' 4,231' 4,239' 10 8/10/2003 Open 'OB' 5,803' 5,832' 4,233' 4,257' 29 5/21/2006 Open 2 5,824' 5,831' 4,250' 4,256' 7 8/10/2003 Open Correlated to SCMT 8/9/2003: 8/10/2003 Perforations—3-3/8",6SPF,60Deg.,PowerJet. I 3 5/21/2006 Perforations-2-1/2",5SPF,45 Deg.,Power Spiral(Strip Gun) a OPEN HOLE/CEMENT DETAIL 5 20" 260 sx Arctic Set(Approx.)in a 42"Hole 4,. A. 4 9-5/8" 70 sx PF'I!,615 sx'E',225 sx'G'in a 12-1/4"Hole y' 11 F;' 7" 310 sx Class'G'in a 8-1/2" a $s Sarts WELL INCLINATION DETAIL il KOP 10 deg.@ 754' 7 I Max Hole Angle=54 deg.@ 4,303' `; Hole Angle thru Perfs=35 deg. 9 TREE&WELLHEAD �] OASandsG N"— Tree 4-1/16"- 5M FMC 1' NES r 11"x4.5"5M Gen 6w/4.5"TC-IIT&B Tubing ¢+ a Wellhead Hanger CIW"H"BPV Profile 1 711 GENERAL WELL INFO A API:50-029-23169-00-00 ' `;12 r Cased&Straddle Completed by Doyon 14 -8/11/2003 Add Perforations—5/21/2006 13 OB Sands "; TOF©5,832 2-1/21 / Strip Gun left in Hole 5/21/2016-10'x y". el 2-1/2'x 1/8" I. 1V I1+ 7" LAI TD=6,235'(MD)/TD=4,586'(TVD) ' PBTD=6,150'(MD)/PBTD=4,516'(TVD) Revised By:TDF 7/27/2015 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - 1 ~ 7 Well History File Identifier o Two-sided 1111111111111111111 Organizing (done) o Rescan Needed 1111111111111111111 RESCAN D~TAL DATA vz1' Diskettes, No..3 o Other, No/Type: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: BY: ( Maria) '"""--- Date: ¡~. cr, o Logs of various kinds: Ú 5 ~ pcul ~ther::MAp /rYI~()rfJ , ...Jð~ ... ~ /) o ~ /s/ VV\- 1111111111I11111111 !J /s/ ~ NOTES: Project Proofing BY: ~ BY: ~ Date: 19- Of. Ð5" X 30 = ?J 0 + ~ 5' = TOTAL PAGES 5 5 ,'ì " (Count does not include cover sheet) ~(¡/. (.) Date: I ~ ~ Ð.s-' /s/ V r . 1111111111111111111 Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: 5 to (Count does include cover sheet) Page Count Matches Number in ScanniJ;1g P-eparation: ~ES J Maria) Date: fd-1, vS Stage 1 BY: /s/ NO :!) Wi If NO in stage 1 page(s) discrepancies were found: YES NO BY: Maria Date: /s/ 1111111111111·1 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder I 4 i Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 0 air Anchorage, Alaska 99501 \` Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, ti ) Mehreen Vazir BPXA, Well Integrity Coordinator III III 1 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPS -Pad 10/1112011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS -01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/312009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS -09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7129/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31 /2011 MPS-16 2030650 50029231510000 1.2 NA 1.2 NA 102 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated , MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7292011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7 /28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 102 7/28/2011 MPS-25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7282011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 12 NA 11.9 7 /282011 MPS -31 2020140 50029230660000 Open Flutes - Treated MPS -32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 7 /28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission TO: Jim Regg � DATE: Thursday, September 15, 2011 P.I. Supervisor ' 1ef/( td 1 I II SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -02 FROM: Bob Noble MILNE PT UNIT SB S -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry c.373e-- NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S - 02 API Well Number: 50 029 - 23169 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110909171358 Permit Number: 203 -127 -0 Inspection Date: 9/9/2011 Rd Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-02 ' Type Inj. W TVD 4007 ' IA 10 [ 1715 - 1660 - 1635 - P.T.D 2031270 - TypeTest S Test psi 1500 - OA 0 100 100 100 Interval 4YRTST P/F P - Tubing 899 899 899 899 Notes: Thursday, September 15, 2011 Page 1 of 1 • • ;=i= WELL LOG ( "i — v TRANSMITTAL PwAciriw DiAgNOSTiC SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 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: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka — LR2 -1 G 900 Benson Blvd. Anchorage, Alaska 99508 NOV and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 c ;26 3 — (c5 2 Fax: (907) 245 -8952 C96 �lya- 1 ] Injection Profile 07- Nov-1O MPU S -02 BL / EDE 50 -029- 23169 -00 Signed: �' Date : "'L Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL: pdSanchorageamemorylog.com WESSITE : www.memoryloci.com C:\Documents and SetbnpUane Wi lliams\Desktop \Tcansmit_BP.doex • • ~~~P ~ ~ ~~~ ~ . ~ ~ ~ ~ .~, ,~ ~ ~~ ~ ~ ~.. ~ w ~E~ ~' ~~ ` `~_ ~ p~ ~ p ~ ` ~ ~~ ~ ~ ~ ~~ " ` ~ ~ SEAN PARNELL, GOVERNOR ~,~ ~ ~~{ ~ ~ ~ q ,~ ~ , }~~ ~ t~ . , . .Y . . .. . ~ .~ ~~$ ~ ~ ~ ~v> .. ~~~~~_~~ ~~ ~. 11itt~-7F1~ OI.a~ Lu~L t][t~-.7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T COMI~IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 October 20, 2009 Mr. Harry Engel Engineering Team Leader BP Exploration (Alaska) Tnc. P.O. Box 196612 Anchorage, AL 99519-6612 "~'=~''~~`~~~~~ 't;~ r W':~~ ~~~~ Re: Milne Point Unit, Schrader Bluff Oil Pool, MPS-02 MPS-09, MPS- l0A and MPS-26 03-127 202-020, 205-125 and 203-061 BP Exploration (Alaska) Inc. Dear Mr. Engel: Enclosed are the work descriptions for subsurface well treatments in the listed wells that were erroneously submitted containing information and operational details proprietary to BP. These work descriptions have been replaced with the edited documents you supplied. Sincerely, ~.~ Thomas E. Maunder, PE Sr. Petroleum Engineer Enclosures (4) ^ 'RO Co~~Ls ~1~i+~ cJ ~ ~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF tSl~, NDRY WELL OPERATIONS ~~~ 1. Operations Abandon ~ Repair Well Plug Perforations ~ Stimulate~ Omer ~pBE REPAIR Pertormed: Alter Casing ~ Pull Tubing ~ ~erforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re~nter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~ 203-1270 , 3. Address: P.O. Box 196612 St~'dtlgfclphlC r Service (:/ 6. API Number: Anchorage, AK 99519-6612 50-029-23169-00-00 , 7. KB Elevation (ft): 9. Well Name and Number: 72.13 KB MPS-02 8. Property Designation: 1.~ ~ 10. Field/Pool(s): ADLO-380110~ ~~ ~ Milne Point Field/ Sdirader Bluff Pool 11. Present Well Condition Summary: Total Depth measured 6235 feet ~ Plugs (measured) None true vertical 4585.71 feet ~ Junk (measured) 5832' S/21/06 Effective Depth measured 6150 feet ` true vertical 4516.15 feet~ Casing Length Size MD TVD Burst Coilapse Conductor 77 20" 94# H-40 35 - 112 35 - 112 1490 470 Surface 2899 9-5/8" 40# L-80 34 - 2934 34 - 2438 5750 3090 Production 6203 7" 26# L-80 32 - 6235 32 - 4586 7240 5410 f ~~ ~; ~~ ~ ~ `+i , _ . _ ~_ L1 t '~ . ` Perforation depth: Measured depth: see attached - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 30 - 5804 ~ 0 0 -~• ~T (~i S wo C-~c_eJZcy P k SSSV t d h / i TCII P d 5516 " ers and ( ype an measured dept ) 3-1 Baker Prem er ~~~`,~~ ~e~ ac 2 a cer ~ " 3-1/2 Baker Premier TCII Padcer 5681 ~ 3-1/2" Baker S Hydroset Padcer 5780 ~~~~~-~~ 0 0 12. Stimulation or cement squeeze summary: ` `"" ". Intervals treated (measured): m; ~ r f,.,,, ! ' ~p ~y ,~ ~ ~ N. . Treatment descriptions induding volumes used and final pressure: E. . , 13. Representative Daily Average Production or Injection Data "' Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 914 Subsequent to operation: 1059 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory (- Development r Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil (- Gas I~ WAG r GiNJ r WtNJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-212 Contact Paige Sloan Printed Name Paige Sloan TiUe Production Engineer Signature~~ Phone 564-4278 Date 9/1/2009 Form 10-404 Revised 04/2006 ~ ' ' ~ ~~~, ~ ~4u €~ ~~ ~(~Q4 ~j+ Submit Original Oniy ~; ° ' ~ ~ . L_-Y~%. C.. M PS-02 203-127 o~oc eTrer~u~u~uT • Sw Name Operation Date Perf Operation Code Meas Depth Top`~ Meas~Depth Base Tvd Depth Top Tvd Depth Base MPS-02 8/10/03 PER 5,572. 5,603. 4,049.98 4,074.07 MPS-02 8/10/03 PER 5,734. 5,765. 4,177.85 4,202.75 MPS-02 8/10/03 PER 5,800. 5,810. 4,230.97 4,239.05 MPS-02 8/10/03 PER 5,824. 5,831. 4,250.37 4,256.03 MPS-02 8/10/03 STC 5,516. 5,681. 4,007.13 4,135.54 MPS-02 8/10/03 STC 5,681. 5,780. 4,135.54 4,214.83 MPS-02 9/12/03 STO 5,516. 5,681. 4,007.13 4,135.54 MPS-02 9/12/03 STO 5,681. 5,780. 4,135.54 4,214.83 MPS-02 5i21/06 APF 5,803. 5,832. 4,233.39 4,256.84 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ ~ MPS-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIOS EVENT SUMMARY ACTIVITY DATE ~ ~ '~ , 03/Au /2009 Ri u Schlumber er um in services for el treatment. 04/Aug/2009 Gel Treatment. RU SLB batch mixer and pump van. Pump injectivity test. Pump gel stage with cross link additive. Job cont' on 8/5/09. 05/Aug/2009 Gel Treatment Cont' from 8/6/09 WSR. Pump gel with cross link per program and freeze protect well with methanol. Notify pad operator of well status. RD and move pumping operations. ***Job Com lete*** FLUIDS PUMPED BBLS 26 Methanol 410 Gel 273 Produced Water • ~`F, ~ ~ r w e,~ ~ ~~ ~H_~ K ~ ~ i s ~ i ~~ ~ ~~ ~ ~ ~~ ~' .~~C~ ~~ ~~ ~rw ~'~~Ci ~! p'._. G F.~ r.~~' a.`~an ~°~ ~ r°~ry ~a~ w y ~ `~ ~~ p ~~ ~`" 3 ~` E - ~~~ ~~ ~j%Y ~`~, ~~~ ~~~~ ~~I~ k ~ ' ~ ~ ~~~ ~ ~~ ~'~~ ' ~`` : ~ ~ ~ ~~ ~~~ O~ ~ ~ COI~TSERQATIOI~T COl-~II5SIOI~T Paige Smith Production Engineer BP E~loration (Alaska) Inc. P.O. Box 196612 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, Alaska 99519-6612 ~-~ 3-~ a. ~ Re: Milne Point Field, Schrader Bluff Pool, MPS-02 Sundry Number: 309-212 `~~~~N~~~ ~UW ~ ~ 2+~JG~ Dear Ms. Smith: 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. When providing notice for a representative of the Conunission to witness any required test, contact the Commission's petroleum field inspector at (907J 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 Corrunission 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 to Superior Court unless rehearing has been requested. Sincerely, Daniel T. S°amount, Jr. ~ Chair DATED this ~ day of July 2009 Encl. f~~ O~ ,~ . .. v' i/p~ STATE OF ALASKA ~~ ALAS~IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 z~~C~~~~ ~:iW/ ~~ .3UN 2 3 2009 ~ ,:;;~~~~:~ s Ai; ~ G~s Cons. C~cnmission A.vrhnr9na 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ PerForate ^ Waiver Other Alter casing ~ Repair well Q, Plug Perforations ~ Stimulate ~ Time Extension ~ POLYMER JOB Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ ~„~~~ .,. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 203-1270 ~ 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23169-00-00 • 7. If perForating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPS-02 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-380110 ~ 72.13 KB . MILNE POINT Field / SCHRADER BLUFF Pool 12• PRESENT WELL CONDIT~ON SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6235 4585.71 6150 4516.15 NONE 5832' 5/21/06 Casing Length Size MD ND Burst Collapse Conductor 77 20" 94# H-40 35 112 35 112 1490 470 Surface 2899 9-5/8"40# L-80 34 2934 34 2438 5750 3090 Production 6203 7" 26# L-80 32 6235 32 4586 7240 5410 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.3# L-80 30 - 5804 Packers and SSSV Type: Packers and SSSV MD (ft): 7" BAKER PREMIER PKR-TC 5516' 7" BAKER PREMIER PKR-TC 5681' 7" BAKER S-3 PKR 5780' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ~ Service Q• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/7/2009 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q. WDSPL ~ Commission Representative: Prepared by Gary Preble 564-4944 18. i hereby certiy that the foregoing is true and correct to the best of my knowledge. Contact GARY PREBLE Printed Name pAIGE SMITH Title pRODUCTION ENGINEER Signature Phone Date 564-4728 6/23/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3o C~_Z !~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ~ Other: ~~~~~~~~ J~_~~ ,{ a~ ~QQ Subsequent Form Required: t-~l..~ c (~_ ,i ]~ j,$ ,~[,~.~~7~ ~ V v \ `~ ~`S ` i~L, '~'J ~~`C h nC ~ s '~~tC~ ~ ~~ v~~~ i. . ~ c: C .. . l ~ " ISS(Of~ ~' ~ ~y ~C_ ~~~~Df APPROVED BY ~e Approved by: COMMISSIONER THE COMMISSION Date: 7 l Form 10-403 Revise ~~~, ~'~jl ~'~ ~ 2009 i~~1~ I , ~ ~ ~ ~~ ~ ~~ ~ ~ Submit in Du h t l~ ~ M PS-02 203-127 PFRF OTTOrHMFNT • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top 7vd Depth Base MPS-02 8/10/03 PER 5,572. 5,603. 4,049.98 4,074.07 MPS-02 8/10/03 PER 5,734. 5,765. 4,177.85 4,202.75 MPS-02 8/10/03 PER 5,800. 5,810. 4,230.97 4,239.05 MPS-02 8/10/03 PER 5,824. 5,831. 4,250.37 4,256.03 MPS-02 8/10/03 STC 5,516. 5,681. 4,007.13 4,135.54 MPS-02 8/10/03 STC 5,681. 5,780. 4,135.54 4,214.83 MPS-02 9/12/03 STO 5,516. 5,681. 4,007.13 4,135.54 MPS-02 9/12/03 STO 5,681. 5,780. 4,135.54 4,214.83 MPS-02 5/21/06 APF 5,803. 5,832. 4,233.39 4,256.84 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . • Maunder, Thomas E (pC?A) From: Engel, Harry R [Harry.Engel@bp.com] Sent: Wednesday, August 12, 20d9 7:49 AM To: Maunder, Thomas E (DOA) Subject: Revised Procedures for AOGCC re: MPU gei treatments Attachments: MPS-02 Gel Treatment.doc; MPS-09LS Gel Treatment.doc; MPS-10LS Gel Treatment.doc; MPS-26SS Gel Treatment.doc ~03-~~-'Z ~~ ~~ ~~ ~ ~ MPS-02 Gel MPS-09LS Gel MPS-10LS Gel MPS-26SS Gel reatment.doc (110 .rreatment.doc (ii..('reatment.doc (10..freatmer~t.doc (85.. Good morning Tom- Enclosed are the procedures I propose for the Milne Pt. Sundries. Please review and let me know if these meet your needs. If so, I recommend we substitute these for what was previously submitted. Thanks for your assistance in this matter. Harry Engel Engineering Team Leader Alaska Drilling & Wells ~~a~~~i ~~dCa et ~: ~~ ZUt~~ ~ ~ . ~~ To: Mark O'Malley/Jerry Sharp Date: June 22, 2009 MPU Well Operations Supervisor From: Paige Smith, MPU Schrader-S Pad Engineer Subject: MPS-02 Gel Job a,~j~ .~ ~ a"\ Step Unit Operation 1 SL Change out WFRV 2 O Shut in all offset roducers and offset in"ector. Bullhead 10 bbl el into MPS-02. 3 O Bullhead ~20 bbls el into MPS-02. Leave well SI for minimum of 2 da s. 4 O Bullhead 10 bbl el into MPS-02. 5 O Bullhead ~500 bbl gel down MPS-02. Keep well and offset producers and injectors shut in for minimum of 7 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water from its preferential path. Measure of success 1. Gel treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient (~900 psi for MPS-02). • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant gel per guidance from the Environmental Team. PROCEDURE Stage 1. Change out WFRV 1. RUSL, hold pre-job safety meeting 2. Change out WFRV Stage 2. Injection Test 3. RU, hold pre-job safety meeting, PT surface lines 4. Ensure offset injectors and producers are SI 5. Spear in with 1-2 barrels of Methanol, pump 100 bbls produced water preflush, 10 bbls gel and 100 bbls produced water over flush. Pump at 1 bpm with a max pressure 1550psi (frac ~ ~ pressure + estimated friction). Attempt to hold injection rate constant while adjusting pressure as needed. 6. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 3. Low Volume Ge/ Treatment 7. Ensure offset injectors and producers are offline 8. Pump 50 bbls produced water preflush, ~20 bbls gel and 30 bbls produced water over flush followed by 22 bbls freeze protect. Pump at 1 bpm or a max pressure 1550psi WHIP (frac pressure + estimated friction). However, injection pressure limits may be exceeded as necessary to avoid trashing the wellbore by leaving gel in the tubing or liner. 9. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 10. Keep well and offset injectors and produces SI for a minimum of 2 days. Stage 4. Injection Tesf 11. RU, hold pre-job safety meeting, PT surface lines 12. Ensure offset injectors and producers are SI 13. Spear in with 1-2 barrels of Methanol, pump 100 bbls produced water preflush, 10 bbls gel and 100 bbls produced water over flush. Pump at 1 bpm with a max pressure 1000psi (frac pressure + estimated friction). Attempt to hold injection rate constant while adjusting pressure as needed. 14. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 5. High Volume Gel Treatment 15. Ensure offset injectors and producers are offline 16. Pump 50 bbls produced water preflush, ~500 bbls gel and 80 bbls produced water over flush followed by 22 bbls freeze protect. Pump at 1 bpm or a max pressure 1000psi WHIP (frac pressure + estimated friction). However, injection pressure limits may be exceeded as necessary to avoid trashing the wellbore by leaving gel in the tubing or liner. 17. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 18. Rig down all equipment and hold post-job assessment meeting to capture learnings to be incorporated into future jobs. 19. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. . i` Tree. 4 1116" - 5M FMC ~~~~' 11' x 4_5" 5M Gen 6 w! 4 5' TCI I T&B T dng Hanger nnPU s-o2~ . u CIW `N' BPV profile KOP 10 deg ~ 754 ` Max. hole angie = 61 deg ~ 4303•~ Flde angle thtu Perfs = 35 de9 ~ ! ~ ~ c~ a-are- e s~ eo a~. ~xc r; c~_ 0 C:OAfiAEP~fTS Cesed d Straddle Compktion Ooyon - 14 Add Perf, Updale WLEG, Update Scherrelic Size Spf Irtterval (1'VD) 3-3f8' B ~ 5,577 - 5.800' a6s~ds 4,050' -4,Q74' 3318' 6 5.734' - 5.785 na ~ i.17T - 4.203 3-318' 8 5.8'DO' - 5,810' 4,231' -4,23G' 2-1f1' S 5.803' - 5.83Y ~.233' - 4.256' 33lS' 8 5,824' - 5.831' 4.250' -4,25b' 6 150' T-1a~'iburtan Floec cdl~ FeTn 6 235' T Hatibi.ton float stwe ca~: z-~2' . 5 sPF. ~s dep. Pawr Spiral (sb+P ~1 DATE REV. BY I7BJ17f03 MDO 05R1JU8 MOR ~D• x 34' nwlaAed, 215 #Nt A-63 117 9 5/8 IDf~, L-80. BTC (driR ID = 8.679, cap = 0_0758 bpi) Zg~• 3_~^. 92# L~0 IHT kibirp ( ID = 2.992'. cap = .0087 8PF ) T 2B1F. L-80. IBT MOD Cesirg (drilt id = 9.151. caP = -0383 bpf) Pertoration Summary CanNated to SCYT 8M116103 Orig. KB Elev_ = 72_13 Orig. GL Ele~. = 38.30 3.5' FIES X-Nipple ( 2.813' Profle ) 2196~ I 3.5" Baker Pdish bore receptade ( 54K to shear " not sheared ) 5.479' 3_5' F~S X-Nipple ( 2.913' Proti~ ) 5,50~~ T x 3.5' Bdrer Premier Wv. TCII 5,515 3.5' Camco MMM ( 1-t/2' RK Lelch ) 5,542~ I 3.S Camco MMN ( 1-iCI RK Laidi ) 5,6~ ~~ I 3.S FES X-Nippie ( 2813' Profilr ) 5,F70~ T x 3.5' Beker Prcmier PM. TCII 5,681 ~ 3.5' Camoo MMG ( 1-1/2' RK LaMh } 5,706~ I 3.5' Camoo MNG ( 1-112" RK La~ch ) 5,T~~ I T x 4.5' x 3.5' Baker S-3 Pkr 5,780` 3.S HES XN-Pipple ( 2.813' Prafile ~ 5,795' i { 2J50' No Go ) 3.3' YYLEG a~ap 5,804' 5,8U2` ••• SAFETY NOTE `° I 5,832' 2 12' Strip G~n LeR In Flolr (0',~21-06) 70'x272'x118' MiINE POINT UNIT VYELL No: S-07i API : 50-029-231 ~-00 BP EXPLORATION (AK) I -~.. _-~.,,. v~ -^,sy ~. 11 ~ • t a3~o~izoos DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFiche\CvrPgs_InsertsiMicrofilm Marker.doc • VV~LL. ~~i."a- ~ ~~~~~~I ~~L _ _,j; ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~`~~~~~ Jt~~ ~ '~ 20a~ RE : Cased Ho4e/Open Hote/Mechanical togs and f 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 BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. U S~ ~~ ~ Imo' Attn: Robert A. Richey 130 West International Airport Road ~ 15~( ~ Suite C Anchorage, AK 9951 S Fax (907] 245-8951 1) Injection Profile 01-0ct,07 MP S~02i 2) 1 /// ~ ®.--'' Signed Print Name: t ' ~n ri ~s~i ; ; ~ 1~~~~- +~ ~~~' 1 Eft 50-029-23169.00 .,~1`„~ ~ _ ~' Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATWNAL AIRPORT ~ SuITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907245-88952 E-NWIL : pds~nc'sor~me(a)rllerssorNlota.~oln WEBSiTE : w+~w.rrl~lalor~9o~.som D:\1Naster_CopY_00_PDSANC-20~oc\Z Word~Distnbution\Transmittal_Sheets\1Yaztnmt_OtiginaF New.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us J OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Milne Point / MPU / S pad 09/15/07 Mel Iveson ap3- ~a-~ ,~1~(.( S.wy /+, _ I - v Z~ ~~ ~.- /l,j,iJ ~,y~ c'~t~Ly~L'vtv..~ SL~1i~L.'. ~' ~1 ~ ~ ~-~ Packer Depth Pretest Initial 15 Min. 30 Min. Well MPS-02 Type Inj. W TVD Tubing 950 950 950 950 Interval 4 P.T.D. 2031270 Type test P Test psi 1500 Casing 0 1520 1450 1450 P/F P Notes: MIT-IA for 4-year UIC compliance. OA 0 100 100 100 Well MPS-14 Type Inj. W TVD 5811 Tubin 1040 1040 1040 1040 Interval 4 P.T.D. 2031040 Type test P Test psi 1500 Casing 0 1540 1490 1470 P/F P Notes: MIT-IA for 4-year UIC compliance. OA 150 300 300 300 Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P!F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA WeII Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~~9'5.~8~~~ NO Y ~ ~ LU~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPS-02 5-14 09-15-07.x1s . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / M1T) 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 Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk MPU S - 02i Injection Profile 31 - Aug - 06 2) 3) 4) 5) 6) 7) SCANNED '''',', (" 'Jr,!')'; Z {.! t..Wl;"': Print Name: /, fi I' /;¡ Ii.. ( >. .Æ__A>'------/ (J,~ rì.<:.,·H d ç :l11~ .JIII/ & €V\ Signed: Date : OCT 2 4 2006 ~ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ?DSAi'!CHORAGE@MEMORYLOG.COfuJ WEBSITE: V".filVVV.MEMCRYLOG.COiVl U:JC-- --R é)o3 - I J7 D:\OO _ PDSANC-2006\Z _ W ord\Distribution\Transmittat SheetslTransmit_ OriginaL doc 'It" ¡¿if "'ð~ , , ~JV(/()C STATE OF ALASKA . RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSP 142006 . Nt, 1. Operations Performed: . ~Iaska Oil & Gas Cons, ~mlsslon Abandon 0 Repair WellD Plu¡:¡ PerforationsD Stimulate Other Alter Casing 0 Pull TubingD Perforate New PoolO Änchorage WaiverD TIme ExtensionD Change Approved ProgramD Operation ShutdownD Perforate [K] Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 203.1270 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒ 50-029-23169-00-00 7. KB Elevation (ft): 9. Well Name and Number: 72.13 MPS-02 8. Property Designation: 10. Field/Pool(s): ADL-0380110 Milne Point / Schrader Bluff 11. Present Well Condition Summary: Total Depth measured 6235 feet true vertical 4586.0 feet Plugs (measured) None Effective Depth measured 6150 feet Junk (measured) 5832' --10' of 2-1/2" x 1/8" Strip Gun (05-21-06) true vertical 4516.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20" 94# H-40 35 - 112 35.0 - 112.0 1490 470 SURFACE 2899 9-5/8" 40# L-80 35 - 2934 35.0 - 2438.0 5750 3090 PRODUCTION 6203 7" 26# L-80 32 - 6235 32.0 - 4586.0 7240 5410 Perforation depth: SCANNED SEP 2 {) 2005 Measured depth: 5572-5603,5734-5765,5800-5810,5803-5832,5824-5831 True vertical depth: 4050-4074,4177-4203,4231-4239,4233-4256,4250-4256 Tubin¡:¡ ( size, ¡:¡rade, and measured depth): 3·1/2" 9.2# L-80 @ 30 - 5804 Packers & SSSV (type & measured depth): 7" Baker Premier PKR - TCII @ 5516 7" Baker Premier PKR - TCII @ 5681 7" Baker S-3 PKR @ 5780 3-1/2" HES X Nipple @ 2196 12. Stimulation or cement squeeze summary: RBDMS 8Ft SEP ] 8 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -- --- 1432 200 801 Subsequent to operation: -- --- 1365 50 765 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilD GasD WAG 0 GINJD WINJŒ] WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~.~. ...,ø '/ ~JI Phone 564-5174 Date 9/12/06 y Form 10-404 Revised 4/2004 ( RIG I N I AL OS/21/2006 BBLS 1 1 . . MPS-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***WELL S/I ON ARRIVAL*** add perf PERFORATED 5803'-5832' IN TWO RUNS WITH POWER SPIRAL EJ 2.5", 5 SPF, CHARGE DATA PER SPAN 7"29# 0.34" EH, 26.8" PENETRATION, 25.6 GMS, 5 SPF. DECISION MADE BY SLOPE WELL OPS COORDINATOR TO NOT HAVE TOP SHOT @ 5802'. ***NOTE*** 10' X 2" X 1/8" STRIP GUN LEFT IN HOLE FROM FIRST GUN RUN. (PICTURE IN WELL FILE) ***WELL S/I ON DEPARTURE*** FLUIDS PUMPED I Diesel - PT Surface Equipment TOTAL Page 1 ~ 4-1/16" - 5M FMC Wellhead' 11" x 4,5" 5M Gen 6 w/4,5" TCII T&B Tubing Hanger CIW "H" BPV profile 20" x 34" insulated, 215 #/ft A-53 ~ 9 5/8" 40#, L-BO, STC (drift ID ::: 8.679, cap::: 0.0758 bpf) 12933' I KOP 10 deg @ 754 ' Max. hole angle::: 61 deg @ 4303" Hole angle thru perfs::: 35 deg 3.5", 9.2# L-80 1ST tubing ( ID = 2.992", cap::: .0087 SPF ) 7" 26#, L-80, 1ST MOD Casing (drift id ::: 6.151, cap.::: .0383 bpf) Perforation Summary Correlated to SCMT 8109/03 Size Spf Interval (TVD) ~ 3-3/8" 6 5,572' - 5,603' 4,050' - 4,074' ~ 3-3/8" 6 5,734' - 5,765' 4,177' - 4,203' 08 s"nds 3-3/8" 6 5,800' - 5,810' 4,231' - 4,239' 2-1/2" 5 5,803' - 5,832' 4,233' - 4,256' 3-3/8" 6 5,824' - 5,831' 4,250' - 4,256' Guns: 3-3/8" , 6 SPF, 60 deg, Powerjet Guns: 2-1/2" , 5 SPF, 45 deg, Power Spiral (Strip Gun) ~ 7" Halliburton Float Collar PBTD I 6,235'1 7" Halliburton float shoe DATE REV. BY 08/11/03 OS/21/06 MDO MOR Cased & Straddle Completion Doyon - 14 Add Perf, Update WLEG, Update Schematic MILNE POINT UNIT WELL No.: S-02i API: 50..029-23169..00 MPU 5-02i COMMENTS Orig. KB Elev. ::: 72,13 Orig. GL Elev. ::: 38.30 3.5" HES X-Nipple (2.813" Profile) 2196' I 3.5" Baker Polish bore receptacle ( 54K to shear" not sheared) I 5,4 79' 3.5" HES X-Nipple (2.813" Profile) 1 5,505' 7" x 3.5" Saker Premier Pkr. TCII I 5,516' 3.5" Camco MMM ( 1-1/2" RK Latch) 5,542' 3.5" Camco MMM ( 1-1/2" RK Latch) 5,611' 3.5" HES X-Nipple (2.813" Profile) 5,670' 7" x 3.5" Saker Premier Pkr. TCII 5,681' 3.5" Camco MMG ( 1-1/2" RK Latch) 5,706' I 3.5" Camco MMG ( 1-1/2" RK Latch) 5,744' 7" x 4.5" x 3.5" Saker S-3 Pkr 5,780' 1 5,795' I 3.5" HES XN-Nipple ( 2.813" Profile) (2.750" No Go) 3.5" WLEG ELMO *** SAFETY NOTE *** 15,832'1 21/2" Strip Gun Left In Hole (05-21-06) 10' x 2 1/2" x 1/8" BP EXPLORATION (AK) ') WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPS-02, ) UI(j ~OJ0 -·197 February 16, 2006 '3l~3\ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-02 : LAS Data & Digital Log Images: 50-029-23169-00 fi~1i r~ r'D 1" ~~\ 2 t! n \3 ~CANNE[ì) ?,l1~tU"\\ ~,~ (\/, 1 CD Rom ~ŸJ-n 8\ ~ 0' I D{fl jCJ ~ DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031270 6235 ~/ TVD Well Name/No. MILNE PT UNIT 58 5-02 Operator BP EXPLORATION (ALASKA) INC s~ !Í~ ~ API No. 50-029-23169-00-00 ,,- Completion Date 8/10/2003"'/ MD Completion Status 4586 1WINJ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GYRO, GR, RES, IFRlCASANDRA, CNL, CDL Well Log Information: Logl Electr Data Digital Dataset Log Log Run Type Med/Fnnt Number Name Scale Media No ~D Directional Survey Final r / Rpt Directional Survey Final -Z D Directional Survey Final Directional Survey Final Æf( 0 Directional Survey Final leø( Directional Survey Final /6t 11980 LIS Verification 1,2 j..5e-" 0 .,...-11980 I nd uction/Resistivity 1,2 ~ ..)Pjection Profile 5 Blu 1 ~ C ~ c...,' 12156 Lr.3 Verification t~J~ Jo C Pds 12156 Cement Evaluation 5 Aog ~ment Evaluation 5 Col ~ C Lis t../:(3190 Injection Profile ~ 13190 Injection Profile Blu Well Cores/Samples Information: Interval Name Start Stop Sent Received Current Status 1WINJ C UIC y\ / Directional surve~ (data taken from Logs Portion of Master Well Data Maint Interval OH/ ~ Start Stop CH Received Comments 0 546 Open 8/29/2003 Gyro, PDF & PTT data files. 0 546 Open 8/29/2003 Gyro 546 6235 Open 8/29/2003 PDF & PTT data files. 546 6235 Open 8/29/2003 546 6235 Open 8/29/2003 MWO, PDF & PTT data files. 546 6235 Open 8/29/2003 MWD 69 6235 Open 9/16/2003 69 6196 Open 9/16/2003 MWD-GR, EWR4, ROP 5300 5793 Case 1 0/8/2003 Injection Profile PSP PFCS/PILS/PBMS 28 6150 Case 10/10/2003 LDWG edit of 1 pass SCMT, GR (PDCL) 100 6138 Case 1 0/1 0/2003 SCMT Cement Bond Log SCMT/PBMS 100 6138 Case 10/1 0/2003 SCMT Cement Bond Log SCMT/PBMS 5300 5850 Case 7/14/2005 5300 5850 Case 7/14/2005 Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031270 Well Name/No. MILNE PT UNIT SB 5-02 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23169-00-00 MD 6235 TVD 4586 Completion Date 8/10/2003 Completion Status 1WINJ Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? Y @ Daily History Received? ÐN '@N Chips Received? - Y IN' Formation Tops Analysis Y / r~ Received? Comments: ~ Compliance Reviewed By: ~ Date: 17Ifo-v~~ ~- ) ) MECHANICAL INTEGRITY REPORT' '... :: ?UD DA!E: <i>.ls -6 ~u :.IG RELEJ._S;:: . ~/\f)-o, OPER & FIELD \S? ~\\~<è:'?<D'\"'~ WEll NUMJJER M \><s -ad- ~ðC)~-\d-T"'ì) """ ,\ Casing: I TD : Q~S- .MD.. '-\$1)<0 TVD; ?BTD: ~\S Ò HJ? 45\ <0 TVD Shoe: (o;>s5MD TVD¡ DV: W~MD \0~·Tvl) ~~LL DATA :....:':ïe'!:" : l.) ~ Shoe: }ill \/. 55\~ SbC(s \ :--.:ioi::g:S :>- Packe:!:" 5,,~~HD ~ole Size <ö \.Iy anå "-.J~ TVD j :OP: HD :".TD ~CH.ANIC;'1.. INTEGRITY - PART /1 T\TD i Set 2. t 55'"\ '";) P er£s C;~lìO 5 ~ ð '-\ ,S"'\~'-\ ~&CJ:J 5<oa ~ to _c;~\ (..J S~~\ 5 ~<o S- :..~ß 's·o~ O~ Annulus Press Test: ~p õ)5S\J ; 15 min d4Çù; 30 min J'-\s<:J ~ e 0= en t s : \J\ \ '\ ~ A('-t.'>~ \0" <:..\-.:. ~ 'Ie... \.. ~ ~ \t \,)C(. c.. / M - 0 ~ ,,/' ;" H:EeRÞ..NleÞ~ INTEGRITY - PART 12 \" '\";) 'c:> \) \ "" ( \.~ \ ~ I\. ~" '{ \ ~ \. ~ <.t. ~ C;.-\-o..:~t. C emen 1: Volumes :', þ...mt. Line.r \"-..J I~ ; Cs g "S \OSX ; DV \'-.) b.. C¡¡¡t -"01 to cove:?: perf s ~ ~Ol~ v... ~ S '-\ ~ h \~ C?\..,)~\,\q "'- \ -\õ CO~<L\ \"ì-~ + 500 I n TheoreticalTOC \....:.~(()'{..S \()~ ~~'lO ~'ò \'0<:'" ~\ \ (J Cement Bond Log (Yes or No) i~ ~ :In AOGCC File \(~~ . eBL :;O:valuation, =one ê.Rove perfs C<6{",-O~'J ~~~~ S\OO \ (). ~O\ù \W.~~'0 S'"\<JJ \. S;W,~() \. ~-~\ S~'6C)\' ~ Pro¿u~tion Log: Typ~ ¡Evaluation CONCLUSIONS: . ~ ?art: n: M \. \"::.<:tJ'l:.hð,,~~J-:- ?ar:: :Z: \J-."S:"\,:> \~~~GYh^ \";rl --D~ . ,_ ~ l:J~y JV \ I(~ '? . . Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# Log Description Date Blueline D.S. 5-16~ \:iq-\i"l) LDL 09/10/03 1 P2-60 ) ~ , -êÃ-i PROD PROFILE W/DEFT 09/13/03 1 H-26 \~5 -~~~ PROD PROFILE 09/17/03 1 E-21A S8HP SURVEY 09/16/03 1 NK-29 )\j'-\~n PROD PROFILe-WIDEFT 09/09/03 1 D.S. 3-29 ' '-n7-~ PROD PROFILE WIDEFT 09/19/03 1 D.S. 15-18 "'-(){ç \ SBHP SURVEY 09/19/03 1 U-08A \~~~ß S8HP SURVEY 09/20/03 1 W-24. LDL 09/23/03 1 D.S. 9-06 \ ~ ~ç(")~ PROD PROFILE WIDEFT 09/20/03 1 D.S. 2-088) -rAt::) 23375 CH EDIT MCNL 05/31/03 1 d-23A Y 23373 OH EDIT LWD IMPULSE DATA 04/30/03 W-23A t13 yy::; ( " 23373 MD VISION RESISTIVITY 04/30/03 1 W-23A 23373 TVD VISION RESISTIVITY 04/30/03 1 W-23A 23373 MD80REHOLEPROALE 04/30/03 1 MPS-0~"-/8_ì 1 0624537 CH EDIT SCMT GR (PDC) 08/09/03 MPS-02 23435 SCMT 08/09/03 MPS-18)' f)ct)Ð4~ 10559235 CH EDIT SCMT GR (PDC) 03/03/03 MPS-18 10559235 SCMT 03/03/03 PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 f.qE:CEü\jED Date Delivered: 1 r-. t'.... ,....~ "CT '.! ,'; i;' <, V j - .-' A18~ke c;·; ¿ l?-L ~-__;n¿;. '~Ù1m¡3~~cn iC'ulC'hoi~g9 09/30/03 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD .--' 1 I~ W 1 ~\·5 1 / 9- 1-F5l () 2 1 J31n T 2 '-" é) Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received~L~Où.>~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well P2-11 II~-l~ Jl7...../ GNI-01 -éJ. ~ D.S. 13-271 lo --I t:).. \: D.S. 6-21A _(t'p~(') D.S.14-32. B ~::s.. J 1).~ C-23B ~ ~ -Oloc'S F-13A 1. ~"'l~~ F-11A ~rJ()-<ll.(,-~ L:1? ,.:~~~~ go~_·t~-=t i~ MPS-20 ~ðL\ \ Job# Log Description Date SBH TEMP & PRESSURE SURVEY TEMP & PRESS SURVEY LDL LDL LDL MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG INJECTION PROFILE 10559234 CH EDIT SCMT (PDC) 10559234 SCMT 10/03/07 10/04/03 10/01/07 10/01/03 10/03/03 09/01/03 09/08/03 09/09/03 10/04/03 03/03/03 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: R~~'<Y\~ c......... ¡" ¡¡;¡='~ i~~~~. .~ _ ;!~~" ~ 'Q; Kt:', ..t:~ V L:U t"\ f'\('¡l'l7. n"'-:- " 'ÎJ....- UI,., I '" U .:.....¡~..; pJaska O~·i é! Ga$ Cons. C:ommission ß\nchor~e Blueline NO. 2984 10/07/03 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints 1 1 1 1 1 1 1 1 1 CD - 2 ~~~ _ r0 {\SÖ .~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~\..~ ~O~"".Af\ ) MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 21 2003 SUBJECT: Mechanical Integrity Test BPX MPU S Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Well 8-14 Type Inj. 8 TV.D. 3673 P.TD. 203-104 Type test P Test psi 918 Notes: prtest pressures observed for 30 minutes OK Well 8-02 Type Inj. 8 TV.D, 4006 P.T.D. 203-127 Type test P Test psi 1002 Notes: Well P.T.D, Notes: Well P.T.D. Notes: Well P.T.D, Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ, S = SALT WATER INJ. N = NOT INJECTING Type Inj. Type test T.V.D. Test psi Type Inj. Type test TV.D. T est psi Type Inj. Type test TV.D. Test psi Pretest Initial 15 Min. 30 Min. Tubing 1550 1550 1550 1550 I nterva I I Casing 750 2550 2450 2450 P/F f Tubing 1500 1500 1500 1500 I nterva I I Casing 800 2550 2450 2450 P/F f Tubing Interval Casing P/F Tubing Interval Casing P/F Tubing Interval Casing P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs MPU 8 Pad and witnessed the initial MIT on wells 8-02 and 8-14. The pretest tubing and casing pressures were observed and found to be stable, The pressure tests were then performed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: º MIT report form 5/12/00 L.G. Total Time during tests: 1 hours cc: MIT MPU S Pad 9-21-03 CS.xls 12/18/2003 ·'\ STATE OF ALASKA " ALASKl.. ,.AL AND GAS CONSERVATION COMI, )SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG o GINJ IB WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3372' NSL, 4729' WEL, SEC. 07, T12N, R11E, UM Top of Productive Horizon: 5078' NSL, 1810 WEL, SEC. 07, T12N, R11 E, UM Total Depth: 162' NSL, 1674' WEL, SEC. 06, T12N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 566062 t y- 6000041~ Zone- ASP4 TPI: x- 568959 y- 6001774 Zone- ASP4 Total Depth: x- 569090 ¡ y- 6002139' Zone- ASP4 18. Directional Survey IB Yes 0 No 21, Logs Run: MWD , GYRO, GR , RES, IFR/CASANDRA , CNL, CDL / 22. CASING, LINER AND CEMENTING RECORD ,'(~Ä$ING, ,.....,.' S'E'T;TI~~Ðr;:eTH/' >"RþL¡SC' "!~: SIZE!, ;: :SO"TOlvV ' ,·,··.SIZE", 20" 94# H-40 35' 112' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 35' 2934' 12-1/4" 70 sx PF 'L" 615 sx 'E', 225 sx 'G' 7" 26# L-80 32' 6235' 8-1/2" 310 sx Class 'G' 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 No. of Completions One Other 5. Date Comp., Susp., or Aband. 8/10/2003/' 6. Date Spudded 8/512003 7, Date T. D. Reached 8/7/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 72,13' 9. Plug Back Depth (MD+ TVD) 6150 + 4516 10. Total Depth (MD+TVD) 6235 ,I + 4586 I 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL Ft Ft 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit Number 203-127 13. API Number 50- 029-23169-00-00 14. Well Number M PS-02i 15. Field and Pool Milne Point Unit I Schrader Bluff 16. Lease Designation and Serial No. ADL 380110 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8" Gun Diameter, 6 SPF MD TVD NB Sands NB Sands . . "':fÚBING,RecORD DEPTH SET (MD) 5802' PACKER SET (MD) 5516' , 5681' 5780' 24. I SIZE 3-1/2",9.3#, L-80 MD OB Sands TVD OB Sands 25. ACIQ, FRACTURE,· CEMENT SQUEEZE,ETC. 5572' -5603' 4050' - 4074' 5800' - 5810' 4231' - 4239' 5824' -~ 4250' - 4256' S<ðs\kî~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 64 Bbls of Diesel OA Sands OA Sands 5734' - 5765' 4178' - 4203' 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF September 15, 2003 Date of Test Hours Tested W A TER-BSL PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ........ OIL-BSL Press, 24-HoUR RATE"'" GAs-McF WATER-BSL '~I=p 1 II JJ~) ~g;"'; \. .... g. . CHOKE SIZE G - t. RATIO ¡¿\. f,} s ~,( G ~~ I· . \~. OIL GRAV1!M,:ABI,lç;.q.RR) ,r ~ _ ~ ..... , ~ \,..,1. { "J ':::'1 _::; '~'-""_1 1"'" ~ . . 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~.ß_·jà:..9-3 ~.'..... J ,.- ." .. ........,... ."--' ORIGINAL Form 1 0-407 Revised 2/2003 CONTINUED ON REVERSE SIDE e,ý ~}S BFL SEP t;, -ì~ 28. SBF2-NA SBF21 SBF24-MF SBF1-NB SBF1-NBR SBF12 SBE4-NC SBE41 SBE2-NE SBE1-NF TSBD-OA TSBC TSBB-OB SBA5 OBD OBE GEOLOGIC MARKER ) NAME MD TVD 5540' 40251 5550' 4033' 5567' 4046' 5573' 4051' 5584' 4059' 5602' 40731 5613' 40821 5621' 4088' 5633' 40981 5690' 4143' 5733' 4177' 5765' 4203' 5800' 4231' 5836' 4260' 5980' 4377' 6058' 44411 29. ~~RMATION TESTS Include and briefly sUmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 30, List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary 31. I hereby certify that the foregoing is true an Signed~·'- Sondra \$tewman_"J?Y-~ MPS-02i Well Number Title rrect to the best of my knowledge. Date ()q ~ (~.. O~~ Technical Assistant Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Steve Campbell, 564-4401 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". Form 10-407 Revised 2/2003 ITEM 29: List all test information. If none, state "None". ') ) BP EXPLORATION Operations Summary Report Legal Well Name: MPS-02 Common Well Name: MPS-02 Spud Date: 8/5/2003 Event Name: DRILL +COMPLETE Start: 8/5/2003 End: 8/10/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 8/10/2003 Rig Name: DOYON 14 Rig Number: From - To Hours Task Code NPT Phase Description of Operations 8/4/2003 14:00 - 17:00 3.00 MOB P PRE Move rig from MPS-14 17:00 - 19:00 2.00 RIGU P PRE Load pipe shed. Nipple up 21" diverter, Rig accept @ 1700 hrs 8/4/2003 19:00 - 22:30 3.50 DRILL P SURF Picking up 63 jts of drill pipe, 17 jts of HWP and Flex dc and standing in derrick, mix spud mud 22:30 - 00:00 1,50 DRILL P SURF M/U Motor, MWD, Orienting same 8/5/2003 00:00 - 00:30 0.50 DRILL P SURF M/U Motor, MWD, Orienting same 00:30 - 01 :00 0.50 DRILL P SURF Function test Diverter, the right to witness test was waived by Chuck Scheve AOGCC 01 :00 - 01 :30 0.50 DRILL P SURF Pre Spud meeting with all personel, fill hole check for leaks 01 :30 - 02:30 1,00 DRILL P SURF Drill from 112' to 293' with 400 GPM, 1000 psi, 80 rpms 02:30 - 03:00 0.50 DRILL P SURF POH - Pick up BHA 03:00 - 03:30 0.50 DRILL P SURF Run Gyro survey 03:30 - 20:30 17.00 DRILL P SURF Drill from 293' to 2940' T. D. 12.25" Surface Hole - 500 gpm - PP on 2830 - off 2530 - RPM 80 - TO on 9K - off 5K - PU 112K - SO 87K - ROT 1 OOK - (Total 5 gyro surveys ran - Last Gyro depth 546') 20:30 - 22:30 2.00 DRILL P SURF CBU 3 X - 12000 strokes - RPM 100 - TO 5K - GPM 500 - PP 2550 - PU 112K - SO 90K - ROT 1 OOK - Stand back stand every 30 mins circulating 22:30 - 00:00 1.50 DRILL P SURF Pump out from 2760' to HWDP @ 815' at @ 420 GPM 8/6/2003 00:00 - 00:30 0.50 CASE P SURF RIH from 815' to 2940' - Hole in good shape - No problems 00:30 - 02:30 2.00 CASE P SURF CBU 3 X - 12000 strokes - 500 GPM - PP 2530 - PU 112K - SO 90K - ROT 100K - RPM 120 - TO 5K 02:30 - 03:30 1.00 CASE P SURF Pump out from 2760' to HWDP @ 815' - Hole in good shape 03:30 - 05:30 2.00 CASE P SURF Rack back HWT and 6" flex collars 05:30 - 06:00 0.50 CASE P SURF Clear rig floor 06:00 - 07:00 1.00 CASE P SURF PJSM (running casing) - Rig up casing tools 07:00 - 09:00 2.00 CASE P SURF Run 69 joints of 95/8" I L-80 I 40# I BTC casing - Shoe 2933' M.D. - Float collar 2847' M.D. - Land on landing ring 09:00 - 09:30 0.50 CASE P SURF Lay down Franks fill up tool - Make up Howco cementing head I lines 09:30 - 12:00 2.50 CASE P SURF Circulate and condition mud for cement job - 250 gpm - 200 psi 12:00 - 14:30 2.50 CEMT P SURF Cement 9 5/8" casing - Howco - Pump 10 bbls fresh water - test lines to 3500 psi - pump 10 bbls water @ 5 bpm - 250 psi - Mix and pump 50 bbls Alpha spacer @ 10.2 ppg - @ 5.5 bpm - 330 psi - (Drop bottom plug on last 5 bbls pumped) (one gallon dye in first 5 bbls pumped of spacer) - Mix and pump 52 bbls Type "L" - 70 sxs @ 10.8 ppg - Yield 4.16 cflsx - @ 5,5 bpm - 270 psi - Mix and pump 238 bbls Type "E" - 615 sxs @ 12.0 ppg - Yield 2,17 cf/sx - @ 5.5 bpm - 300 psi - Mix and pump 46 bbls Class "G" - 225 sxs @ 15.8 ppg - Yield 1.15 cf/sx @ 5.5 bpm - 300 psi - Drop top plug - Kick out with 30 bbls of fresh water with Howco - Give to Rig - Rig displaced cement with 186 bbls mud @ 6 bpm -800 psi - Bump plug with 1800 psi - 1000 psi over displacement rate - 70 bbls cement back on surface 14:30 -15:30 1.00 CEMT P SURF Check floats - Floats holding - Rig down Howco head I lines - Lay down landing joint - Flush annular and flow line 15:30 - 16:30 1.00 CASE P SURF Nipple down divertor system - Clean pits - Rig down casing tools - Change bails 16:30 - 18:30 2.00 CASE P SURF Make up FMC speed head - Test metal to metal seal to 1000 psi / for 15 mins - Test good - Nipple up BOP's Printed: 8/11/2003 10:58:06 AM Legal Well Name: MPS-02 Common Well Name: MPS-02 Spud Date: 8/5/2003 Event Name: DRILL +COMPLETE Start: 8/5/2003 End: 8/10/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 8/10/2003 Rig Name: DOYON 14 Rig Number: Date From- To Hours Task Code NPT Phase Description ofOperatiÓns 8/6/2003 18:30 - 19:00 0.50 CASE P SURF Install test plug - Rig up testing equipment 19:00 - 22:00 3.00 CASE P SURF Test BOP's - Annular 250 low - 2500 high - 5 mins each test - Pipe rams Top I Btm ~ Blind rams 250 low - 3500 high for 5 mins each test - Choke manifold - Hyd choke I Hyd Kill valves - Manual choke / manual kill valves - Upper / lower IBOP - Floor TIW - Floor Dart valves 250 low - 3500 high - 5 mins each test - Test good - Chuck Scheve with AOGCC wavied witness of BOP test 22:00 - 22:30 0,50 CASE P SURF Rig down testing equipment - Pull test plug - Install long bowl wear ring - close annulus valves 22:30 - 00:00 1.50 CASE P SURF Pick up BHA - Make up BHA - Bit - motor with 1.22 setting - MWD - orient - Flex DC's - Surface test MWD - Test good 8/7/2003 00:00 - 00:30 0.50 CASE P SURF RIH to 2830' 00:30 - 01 :30 1.00 CASE P SURF Cut drlg line - Top drive service 01 :30 - 02:30 1.00 CASE P SURF Test 9 5/8" to 2500 psi for 30 mins - Record on chart 02:30 - 03:00 0.50 DRILL P SURF Drill float equipment / cement from 2846' to 2933' - 20' new hole from 2940' to 2960' 03:00 - 03:30 0.50 CASE P SURF Displace with 8.6 ppg mud 03:30 - 04:00 0.50 CASE P SURF Preform FIT - Depth 2960 M.D. Shoe 2933' M.D. Shoe 2441 TVD - Mud weight 8.6 ppg - Surface pressure 370 = 11.51 EMW 04:00 - 04:30 0.50 CASE P SURF Blow down choke manifold - Rig down test lines 04:30 - 23:30 19.00 DRILL P INT1 Directional Drilling from 2960' to 6235' - T.D. 8 1/2" hole section - WOB 35K - RPM 120 - TQ on 10K - off 9K - GPM 425 - PP on 3150 - off 2700 - PU 175K - SO 1 OOK - ROT 117K 23:30 - 00:00 0.50 DRILL P INT1 CBU 3 X - GPM 425 - PP 2550 - RPM 120 - TQ 9K - PU 175K- SO 1 OOK - ROT 117K 8/8/2003 00:00 - 02:00 2.00 CASE P INT1 Con't CBU 3X - GPM 425 - PP 2550 - RPM 120 - TQ 8k - PU 175K - SO 100K - ROT 117K 02:00 - 05:00 3.00 CASE P INT1 Pump out from 6235' to 2930' - Pump out at drlg rate 425 GPM - Spotty tight spots from 4900' to 4000' - Lost 90 bbls mud on trip out through this section - no overpulls or pump increase observed - Flow percent below what was normal - On 5 stands pulled through that section lost 55 bbls on mud on fill - next 5 stands flow was normal to below normal - lost additional 40 bbls - 05:00 - 05:30 0.50 CASE P INT1 Circulated bottoms up at the shoe - No losses observed circulating bottoms up - lot of cuttings up 05:30 - 06:30 1.00 CASE P INT1 Run back to 6150' - wash from 6150' to 6235' - no problems - hole in good shape 06:30 - 09:00 2.50 CASE P INT1 CBU 3 X - GPM 450 - PP 3000 - RPM 100 - TQ 9K - PU 175 - SO 100 - ROT 117 - Pump dry job 09:00 - 12:00 3.00 CASE P INT1 POH from 6235' to 723' @ BHA 12:00 - 13:30 1.50 CASE P INT1 Lay down 8 1/2" BHA 13:30 - 15:00 1.50 CASE P INT1 Change top rams to 7" casing rams - Test body to 1500 psi for 10 mins 15:00 - 16:00 1.00 CASE P INT1 Rig up casing tools (PJSM on running casing) 16:00 - 19:00 3.00 CASE P INT1 Run 7" I 26# I L-80 I BTC-M casing to 2894' - 70 joints 19:00 - 19:30 0.50 CASE P INT1 Break Circulation - Circulate 1 casing volume at 2894' - 50 spm 11930210 gpm - PP 320 19:30 - 20:30 1.00 CASE P INT1 Con't RIH with 7" casing from 2894' to 4180', Hole taking mud while running in open hole. 20:30 - 21 :30 1.00 CASE N DPRB INT1 Mixed and spotted LCM in open hole at 35 spm at 400 psi - 30 Printed: 8/11/2003 10:58:06 AM ') BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-02 MPS-02 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Date From - To Hours Task Code· NPT Phase 8/8/2003 20:30 - 21 :30 1.00 CASE N 21 :30 - 22:30 1.00 CASE P 22:30 - 23:30 1.00 CASE N 23:30 - 00:00 0.50 CASE P DPRB INT1 INT1 DPRB INT1 INT1 INT1 INT1 INT1 8/9/2003 00:00 - 00:30 0.50 CASE P 00:30 - 03:00 2.50 CASE P 03:00 - 05:00 2.00 CEMT P 05:00 - 06:30 1.50 CASE P INT1 06:30 - 07:30 1.00 CASE P INT1 07:30 - 08:00 0.50 CASE P INT1 08:00 - 08:30 0.50 CASE P INT1 08:30 - 10:30 2.00 CASE P INT1 10:30 - 11 :30 1.00 CASE P INT1 11 :30 - 12:00 0.50 EVAL P CaMP 12:00 - 14:00 2.00 EVAL P CaMP 14:00 - 15:00 1.00 EVAL P CaMP 15:00 - 17:00 2,00 EVAL P COMP 17:00 - 22:30 5.50 EVAL P caMP 22:30 - 23:00 0.50 EVAL P caMP 23:00 - 0,00 PERF P caMP 8/10/2003 00:00 - 03:00 3,00 PERF P CaMP Start: 8/5/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 8/5/2003 End: 8/10/2003 Description of Ope rations bbl pill mixed at 7 ppb Continued running in hole with casing to 5635'. Hole continued taking mud while running in open hole. Mixed and spotted LCM pill in open hole at 35 spm - 410 psi - 20 bbl pill - mixed at 7 ppb Con't RIH with 7" casing from 5635' to 6209' - Make up landing joint - Break circulation wash to 6235' - Lost 21 bbls on displacement running 7" casing in hole Lay down Franks fill up tool - Make up cement Circulate I Condition mud I hole - Pump 40 bbl pill mixed at 12 ppb - Circulate pill out - well stable - Lost 30 bbls while circulating - and conditioning hole I mud Howco Pump 5 bbls water - Test lines to 3500 psi - Pump 15 bbls water @ 2 bpm 250 psi - Pump 30 bbls Alpha spacer mixed at 10.2 ppg @ 4 bpm 480 psi (drop bottom plug last 5 bbls spacer on the fly) - Mixed 72 bbls 310 sxs Class "G" with 3% Kcl - 1 % Cal Seal - .5% Lap - mixed at 15.6 - Yield 1.31 - @ 4 bpm 200 psi - Pump 1/2 bbl fresh water - Shut down flush out cement lines from truck to cement head with 10 bbls water) - Displaced with Howco - 241 bbls of 9,7 brine @ 4 bpm 200 psi - slow down last 15 bbls pumped @ 2 bpm 500 psi - Bump plug with 1000 psi over 1500 psi - Held pressure for 5 mins - Bled back into Howco - One bbl back - floats holding - CIP 05:00 hrs - Had full returns through out job - Reciprocated pipe through out circulating and cementing - displacement Flush BOP stack and flowline with fresh water - Blow cement line from Howco to cementing head with air - Blow 30' brine out of casing Change out 7" rams in top set to 2 7/8" x 5" Lay down casing tools I equipment Nipple down BOP's - Pick up stack Set emergency slips on 7" casing - Weight Indicator reading 260K - Blocks 50K - Slips set with 210K Nipple up BOP's - Rig service Top drive - clean up rig floor - Pick up cellar area Lay down 15 stands 4" dp from derrick - Transfer 22 stands from off drillers side to drillers side - Wait on cement to cure Prepare tubing tally - Wait on cemet to cure PJSM - Rig up Schlumberger for E-line logging and perforating - Wait on cement to cure RIH with SCMT log from surface to total depth - Correlation between MWD and Wireline log - 1/2 foot adjustment - Lay down tool Install test plug - Test top rams 2 7/8" X 5" - Test to 250 low 3500 high for 5 mins each test - test good - Lay down test joint - Pull test plug PJSM - Pick up Schlumberger guns - 3 375" / HSD / 3406 I Powerjet / HMX /6 shotlft / 60 phase - Make up Run # 1 - RIH with guns RIH to 5960' - Correlate guns on depth - Guns on depth 5800' to 5810' and 5824' to 5831' - fire guns (Two bblloss observed) - Pull out of hole - Lay down guns - (All shots fired) - Pick up guns for 2nd run - RIH to 5890' - Correlate guns on depth - Printed: 8/11/2003 10:58:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-02 MPS-02 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/5/2003 Rig Release: 8/10/2003 Rig Number: Spud Date: 8/5/2003 End: 8/10/2003 Date From- To Hours Task Code NPT Phase Description of Operations 8/10/2003 00:00 - 03:00 3.00 PERF P COMP Guns on depth 5734' to 5765' - fire guns (Two bblloss observed) - Pull out of hole - Lay guns down - (All shots fired) - Pick up guns for 3rd run - RIH to 5850' - Correlate guns on depth - Guns on depth 5572' to 5603' - Fire guns (Three bbl loss observed) - Pull out of hole - Lay down guns - (All shots fired) - Total Losses through out job 10 bbls on all three runs 03:00 - 04:30 1.50 EVAL P COMP Make up Schlumberger Junk basket I gauge ring - RIH to 6130' - Pull out hole - No set down weight or overpulls with j-basket seen on trip in and out - Clean j-basket - Basket clean - Rig down Schlumberger 04:30 - 06:00 1.50 RUNCOIVP COMP PJSM - Rig up casing equipment to run 3 1/2" completion string - 06:00 - 11 :00 5.00 RUNCOIVP COMP Run 3 1/2" completion - 171 joints I 9.2# I L-80 I IBT 11 :00 - 12:00 1.00 RUNCOIVP COMP Rig up Schlumberger for correlation log 12:00 - 14:30 2.50 RUNCOIVP COMP Run Correlation log for packer setting depth - Packers were 1 foot deep - POH - rig down Schlumberger 14:30 - 15:30 1.00 RUNCOIVP COMP Space out - Land tubing - Baker "s" packer set at 5780' - Baker Premier Hyd packer set at 5681' - Baker Premier Hyd Packer set at 5516' - WLG 5803.56 15:30 -16:00 0.50 RUNCOIVP COMP RILDS - Lay down landing joint - Test TWC to 1000 psi 16:00 - 17:00 1.00 RIGD P COMP Nipple down BOP's 17:00 - 18:00 1.00 RIGD P COMP Nipple up adapter flange - Tree 18:00 - 18:30 0.50 RIGD P COMP Test adapter - Tree to 5000 K.for 10 mins 18:30 - 19:00 0.50 RIGD P COMP Pull TWC with DSM 19:00 - 19:30 0.50 RIGD P COMP Pump 65 bbls diesel down 9 5/8" X 7" annulus @ 2.88 bpm - 700 psi 19:30 - 20:00 0.50 RIGD P COMP Pump 64 bbls diesel down 7" X 3.5" annulus 3 bpm 1100 psi taking returns up tubing 20:00 - 20:30 0.50 RIGD P COMP Drop ball and rod - Rig up to set packers and test annulus I tubing 20:30 - 23:00 2.50 RIGD P COMP Pressure up tubing to 2500 psi - hold for 10 mins - Con't pressure up to 4500 hold for 2 mins - Increase to 4800 hold for 4 mins - bled pressure off to 3000 psi - shut in tubing - holding 3000 for 30 mins - (Annulus valves open for 30 min test) - bled off tubing to 2000 psi - shut in tubing - Pressure up annulus to 3500 psi - hold 3500 for 30 mins - bled off annulus pressure to zero - Bled off tubing pressure to zero - Good test on Tubing and annulus 23:00 - 00:00 1.00 RIGD P COMP Set TWC with FMC - test to 1000 psi with 1 st Energy - Suck out cellar - Secure well - Release rig at 24:00 hrs 8/10/2003 Printed: 8/11/2003 10:58:06 AM Legal Name: MPS-02 Common Name: MPS-02 Test Date 8/7/2003 Test Type FIT Test Depth (TMD) 2,960.0 (ft) BPEXPLORATION Leak-Off TestSÜrnl11äry TestDepth (TVD) 2,441.0 (ft) AMW 8.60 (ppg) Surface Pressure Leak OffPres5ure(BHP) 370 (psi) 1,461 (psi) EMW 11.52 (ppg) ~ ~ Printed: 8/11/2003 10:57:52 AM ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_02 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 6,235.00' MD (if applicable) ') fjQ3-/!J1- 23-Aug-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ú ~~6:b RECEIVED AUG 2 9 2003 AJaaka OH & Gas Cons. Commi35ion Anchomge Sperry-Sun Drilling Services \"-..,. Milne Point Unit BPXA Milne Point MPS MPS;.02 Job No. AKZZOOO2589884, Surveyed: 7 August, 2003 Survey Rèport 22 August, 2003 v Your Ref: AP/S00292316900 Surface Coordinates: 6000041.30 N, 566062.45 E (70024' 37.9759" N, 1490 27' 43.4366" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1000041.30 N, 66062.45 E (Grid) Surface Coordinates relative to Structure: 68.80 N, 281.95 W (True) Kelly Bushing: 72. 13ft above Mean Sea Level Elevation relative to Project V Reference: 72.13ft Elevation relative to Structure: 72.13ft BI=Je=I- ·rty-sLJl'1 DAILLING SERViCes A Halliburton Company DEF'Nlr VE --~ ,. ~ Survey Ref: svy1254 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit Measured Depth (ft) ~ ~~ 546.72 664.35 754.45 852.53 946.94 1043,66 1139.99 1235.74 1330.85 1426.88 1522.81 1617.83 1714.45 1810.47 1906.87 2002.61 2098.72 2194.94 2289.65 2385,54 2481.93 2578.24 2674.12 2769.95 2867.48 2959.01 3055.02 3150.78 3247.47 3341.57 3439.65 3535.35 3631.45 3726.33 3822.60 Incl. 4.400 6.360 8.760 12.330 14.490 18.360 21.100 23.660 27.940 32,850 32,920 33.410 35.360 36,110 38.050 39.150 41.720 44,560 46.770 50.060 53,990 55.500 56.440 56.510 55.600 55.550 55.370 54.750 55.050 54.560 54.430 54.550 54.830 54.740 53.940 22 August, 2003 - 10:17 Azim. 78.000 84.040 82.570 81.910 75.170 75.340 72.840 71.350 66.280 65.580 65.780 65.530 63.540 64,270 63.020 60.710 60.720 62.080 60.990 62.090 61.210 61.440 58.510 57,910 56.990 56.890 56.250 56.640 58.460 59.060 58.570 59.130 58.960 59.430 58.950 Sub-Sea Depth (ft) 474.21 591,32 680.63 777.03 868,87 961.63 1052.29 1140.83 1226.45 1309.25 1389.81 1469,35 1549.09 1627.03 1703.93 1778.76 1851.91 1922.11 1988.30 2051.93 2111.23 2166.82 2220.49 2273.41 2327.88 2379.62 2434.06 2488.90 2544.50 2598.74 2655.70 2711.28 2766.83 2821.54 2877.67 Vertical Depth (ft) 546.34 663.45 752.76 849.16 941.00 1033.76 1124.42 1212.96 1298.58 1381.38 1461.94 1541.48 1621.22 1699.16 1776,06 1850.89 1924.04 1994.24 2060.43 2124.06 2183.36 2238.95 2292.62 2345.54 2400.01 2451.75 2506,19 2561.03 2616.63 2670.87 2727.83 2783.41 2838.96 2893.67 2949.80 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-02 Your Ref: AP/500292316900 Job No. AKZZOOO2589884, Surveyed: 7 August, 2003 Local Coordinates Northings Eastings (ft) (ft) 4.12 N 5.73N 7.14 N 9.58N 14.02 N 20.97 N 29.93 N 41.16N 56.24 N 76.07 N 97.52 N 118.95 N 142.42 N 167.09 N 192.90 N 221.07 N 251.56 N 283.04 N 315.33 N 349.49 N 385.58 N 423.31 N 463.07 N 505.16 N 548.69 N 589.87 N 633.44 N 676.83 N 719.27 N 759.16 N 800.50 N 840.79 N 881.13 N 920.83 N 960.89 N 14.63 E 25.52 E 37.29 E 55.07 E 76.4 7 E 102.91 E 134.17 E 168.84 E 207.35 E 251.69 E 299.15 E 346.51 E 395.75 E 446.12 E 498.19 E 550.84 E 605.21 E 662.98 E 722.52 E 785.57 E 852.42 E 921.42 E 990.20 E 1058.10 E 1126.30 E 1189.58 E 1255.58 E 1320.99 E 1387.75 E 1453.49 E 1521.80 E 1588.47 E 1655.72 E 1722.30 E 1789.48 E Page 2 0'4 Global Coordinates Northings Eastings (ft) (ft) 6000045.55 N 6000047.26 N 6000048.77 N 6000051.36 N 6000056.00 N 6000063.18 N 6000072.42 N 6000083.95 N 6000099.37 N 6000119.59 N 6000141.46 N 6000163.31 N 6000187.22 N 6000212.33 N 6000238.60 N 6000267.24 N 6000298.21 N 6000330.19 N 6000363.01 N 6000397.72 N 6000434.40 N 6000472.74 N 6000513.11 N 6000555.80 N 6000599.93 N 6000641.67 N 6000685.82 N 6000729.79 N 6000772.82 N 6000813.28 N 6000855.23 N 6000896.11 N 6000937.04 N 6000977.33 N 6001017.98 N 566077.04 E 566087.92 E 566099.67 E 566117.43 E 566138.79 E 566165.17 E 566196.35 E 566230.92 E 566269.29 E 566313.45 E 566360.73 E 566407.89 E 566456.93 E 566507.07 E 566558.91 E 566611.32 E 566665.41 E 566722.90 E 566782.15 E 566844.90 E 566911.42 E 566980.09 E 567048.51 E 567116.04 E 567183.85 E 567246.76 E 567312.38 E 567377.41 E 567443.78 E 567509.17 E 567577.11 E 567643.42 E 567710.31 E 567776.54 E 567843.36 E BPXA Dogleg Vertical Rate Section Comment (01100ft) 1.732 2.672 3.642 2.821 4.002 2.976 2.738 5.059 5.126 0.135 0.535 2.329 0.898 2.159 1.894 2.674 3.106 2.474 3.537 4.140 1.580 2.716 0.527 1.218 0.105 0.580 0.728 1.571 0.737 0.428 0.493 0.325 0.416 0.924 14.37 AK-6 BP _IFR-AK 24.24 34.72 50.72 70.84 96.54 127.33 162.23 202.47 250.21 -" 301.44 352.58 406.43 461.87 519.37 5(:8.70 640.76 706.16 773.50 844.78 920.28 998.49 1077.67 1157.45 1238.30 --- 1313.77 1392.84 1471.32 1550.36 1627.12 1706.81 1784.56 1862.81 1 940.15 2018.18 DrillQuest 3.03.02.005 Sperry-Sun ··Dtilllt!g~~fJrvices Survey Report for Milne- PiJftifMPS . MPS-D2 Your Ref: AP/500292j16900 Job No. AKZZOOO2589884, Surveyed: 7 August, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3918.30 53.900 59.220 2934.02 3006,15 . 1000.63 N 1855.83E 6001058.30 N 567909.36 E 0.232 2095.36 4014.77 54.210 59.140 2990.65 3062.78 1040.64 N 1922.90 E 6001098.91 N 567976.07 E 0.328 2173,28 4109.86 54.050 59.300 3046.37 3118.50 1080.07 N 1989.11 E 6001138.93 N 568041.92 E 0.217 2250.15 4206.07 53.250 60.360 3103.40 3175,53 1119.02 N 2056.09 E 6001178.46 N 568108.57 E 1,216 2327.40 4303.20 53.730 61 .260 3161.19 3233.32 1157.09 N 2124.25 E 6001217.14 N 568176.38 E 0.894 2405.10 .,.....~ 4399.13 53.480 60.550 3218.11 3290.24 1194.64 N 2191.72 E 6001255.28 N 568243.52 E 0.650 2481.95 4494.86 53.030 60.120 3275,38 3347.51 1232.60 N 2258.38 E 6001293.83 N 568309.84 E 0.592 2558.36 ~/ 4590.00 52.740 60.740 3332.79 3404.92 1270.04 N 2324.36 E 6001331.85 N 568375.49 E 0.602 2633.92 4685.85 51.810 60.470 3391.43 3463.56 1307.25 N 2390.41 E 6001369.64 N 568441.21 E 0.996 2709.41 4782,17 50.790 60.350 3451.66 3523.79 1344.37 N 2455.78 E 6001407.34 N 568506.24 E 1,063 2784.28 4877.66 51.410 57.580 3511,63 3583.76 1382.68 N 2519.44 E 6001446.21 N 568569.56 E 2.349 2858.43 4973.89 52,390 57.060 3571.01 3643.14 1423.57 N 2583.18 E 6001487.67 N 568632.94 E 1.104 2934.10 5071.87 50.630 55.560 3631.99 3704.12 1466.10 N 2646.99 E 6001530.75 N 568696.37 E 2.159 3010.77 5168.22 49.540 53.090 3693.81 3765.94 1509.18 N 2707.02 E 6001574.36 N 568756.02 E 2.268 3084.65 5263.90 48.070 51.410 3756.83 3828.96 1553.24 N 2763.95 E 6001618.93 N 568812.55 E 2.026 3156,54 5360.14 45,870 47.260 3822.51 3894.64 1599.03 N 2817.32 E 6001665.19 N 568865.51 E 3.893 3226.48 5456.65 43,550 43.440 3891.11 3963.24 1646.69 N 2865.63 E 6001713.27 N 568913.40 E 3.678 3293.34 5552.34 39.700 35.550 3962.68 4034.81 1695.55 N 2906.11 E 6001762.48 N 568953.45 E 6.790 3354.43 5648.28 37.870 28.850 4037.49 4109.62 1746.30 N 2938.15 E 6001813.52 N 568985.04 E 4.770 3409.67 5743.30 36.600 21.340 4113.18 4185.31 1798.25 N 2962.55 E 6001865.69 N 569008.97 E 4.963 3459.31 5839.36 35.880 16.150 4190.68 4262.81 1851.98 N 2980.80 E 6001919.57 N 569026.75 E 3.280 3504.91 5934.42 35.590 16.240 4267.84 4339.97 1905.30 N 2996.29 E 6001973.02 N 569041.77 E 0.310 3548.00 6030.85 35.090 16.460 4346.50 4418.63 1958.82 N 3011.99 E 6002026.68 N 569056.99 E 0.535 3591.38 6128.09 35.050 16.940 4426.09 4498.22 2012.33 N 3028.04 E 6002080.34 N 569072.57 E 0.287 3635.05 6169,51 35,080 17.400 4459.99 4532.12 2035.07 N 3035.07 E 6002103.13 N 569079.40 E 0.642 3653.77 -- ....6235.00 35.080 17.400 4513.58 4585.71 .... 2070.98 N 3046.32 E 6002139.15 N 569090.33 E 0.000 3683.48 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 55.290° (True). Magnetic Declination at Surface is 25.4200(05-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 6235.00ft., 22 August, 2003 - 10:17 Page 3 of 4 DrillQuest 3.03.02,005 Sperry-Sun Dril/i"j}tServices Survey Report for Mllne;PolnfMPS- MPS-02 Your Ref: AP/5002923169DD Job No. AKZZOOO2589884,Surveyecl: 7 August, 2003 BP EXPLORA r/ON (ALASKA) INC. Milne Point Unit BPXA The Bottom Hole Displacement is 3683.62ft., in the Direction of 55.791° (True). Comments \....- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6235.00 4585,71 2070.98 N 3046.32 E Projected Survey .~ Survey too/prOgram for MPS-02 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 546.72 0,00 546.34 546.72 6235.00 546.34 Tolerable Gyro (MPS-02 Gyro) 4585.71 AK-6 BP _IFR-AK (MPS-02) ---- 22 August, 2003 - 10:17 Page 4 0'4 DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_02 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 6,235.00' MD (if applicable) ) [)03·~-19T- 23-Aug-03 Please call me at 273-3545 if you have any questions or concerns. Regards, Will iam T. Allen Survey Manager Attachment(s) ~~~Y'^-~ RECEIVED AUG 2 9 2003 Ala8ka ŒI tit Gas Cent. CommiMJion Anchorage Sperry-Sun Drilling Services ...,,-- Milne Point Unit 8ÞXA MilnePoinfMPS MPS-02 MWD -' Job No. AKMW0002589884, Surveyed: 7 August, 2003 Survey;1I.s/fJort 22 August, 2003 Your Ref: AP/500292316900 Surface Coordinates: 6000041.30 H, 566062.45 E (70° 24' 37.9759" N, 149027'43.4366" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 ~/ Surface Coordinates relative to Project H Reference: 1000041.30 H, 66062.45 E (Grid) Surface Coordinates relative to Structure: 68.80 N, 281.95 W (True) Kelly Bushing: 72. 13ft above Mean Sea Level Elevation relative to Project V Reference: 72.13ft Elevation relative to Structure: 72.13ft SpE!!r'I'Y--SSUI! DRIL.L.ING ·SEAVlces A Halliburton Company Survey Ref: svy1255 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS-02 MWD Your Ref: AP/500292316900 Job No. AKMWOO02589884, Surveyed: 7 August, 2003 BP EXPLORA r/ON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 546.72 4.400 78.000 474.21 546.34 4.12 N 14.63 E 6000045.55 N 566077.04 E 14.37 MWD Magnetic 664.35 6.360 84.090 591.32 663.45 5.73 N 25.52 E 600004 7 .25 N 566087.92 E 1.733 24.24 754.45 8.760 82.610 680.63 752.76 7.12 N 37.29 E 6000048.75 N 566099.68 E 2.672 34.71 852.53 12.330 82.030 777.03 849.16 9.54N 55.07 E 6000051.32 N 566117.44 E 3.641 50.70 946,94 14.490 75.150 868.87 941.00 13.96 N 76.48 E 6000055.94 N 566138.80 E 2.841 70.82 ',,- 1043.66 18.360 75.320 961.63 1033.76 20.92 N 102.92 E 6000063.13 N 566165.18 E 4.002 96.52 1139.99 21.100 72.700 1052.29 1124.42 29.93 N 134.16E 6000072.41 N 566196.34 E 2.988 127.32 -- 1235.74 23.660 71,170 1140.83 1212.96 41.26 N 168.80 E 6000084.05 N 566230.88 E 2.742 162.25 1330.85 27.940 67.080 1226.44 1298,57 56.10 N 207.41 E 6000099.23 N 566269.35 E 4.871 202.44 1426.88 32.850 65.510 1309.25 1381.38 75.67 N 251.86 E 6000119.20 N 566313.63 E 5.179 250.13 1522.81 32.920 65.680 1389.81 1461.94 97.19 N 299.29 E 6000141.14 N 566360.87 E 0.121 301.37 1617.83 33.410 65.530 1469.35 1541 .48 118.66 N 346.63 E 6000163.02 N 566408.02 E 0.523 352.51 1714.45 35.360 63.440 1549.08 1621.21 142.18 N 395.86 E 6000186.98 N 566457.03 E 2.359 406.37 1810.47 36.110 64.390 1627.03 1699.16 166.84 N 446.22 E 6000212.08 N 566507.18 E 0.972 461.82 1906.87 38,050 62.930 1703.93 1776.06 192.64 N 498.30 E 6000238.34 N 566559.02 E 2.210 519.32 2002.61 39.150 60,730 1778.76 1850.89 220.84 N 550.94 E 6000267.01 N 566611.41 E 1.837 518.65 2098,72 41.720 60.120 1851.90 1924.03 251.62 N 605.14 E 6000298.26 N 566665.34 E 2.705 640.73 2194.94 44.560 62.010 1922.11 1994.24 283.42 N 662.73 E 6000330.57 N 566722.64 E 3.243 706.17 2289.65 46.770 60,680 1988.30 2060.43 315.91 N 722.16 E 6000363.59 N 566781.79 E 2.540 773.53 2385.54 50.060 62.160 2051.93 2124.06 350.20 N 785.14 E 6000398.43 N 566844.46 E 3.620 844.83 2481.93 53,990 60.840 2111.23 2183.36 386.46 N 851.89 E 6000435.28 N 566910.89 E 4.218 920.35 2578.24 55.500 61.310 2166.83 2238.96 424.50 N 920.72 E 6000473.92 N 566979.38 E 1.618 998,59 2674.12 56.440 58.900 2220.49 2292.62 464.10 N 989.60 E 6000514.14 N 567047.90 E 2.302 1077.76 2769.95 56.510 58.010 2273.41 2345.54 505.90 N 1057.68 E 6000556.53 N 567115.61 E 0.778 1157.53 2867.48 55.600 57.170 2327.88 2400.01 549.26 N 1125.98 E 6000600.50 N 567183.53 E 1.175 1238.37 _/ 2959.01 55.550 57.380 2379.62 2451.75 590.08 N 1189.50 E 6000641.87 N 567246.68 E 0.197 1313.83 3055.02 55.370 56.820 2434.06 2506.19 633.03 N 1255.90 E 6000685.42 N 567312.70 E 0.516 1392.87 3150.78 54.750 56.850 2488.90 2561.03 675.98 N 1321.61 E 6000728.94 N 567378.03 E 0.648 1471.34 3247.47 55.050 58.840 2544.50 2616.63 718.07 N 1388.58 E 6000771.63 N 567444.63 E 1.712 1550.36 3341.57 54.560 59.430 2598.74 2670.87 757,52 N 1454.59 E 6000811.66 N 567510.28 E 0.731 1627.09 3439.65 54.430 59.060 2655,70 2727.83 798.35 N 1523.20 E 6000853.09 N 567578.53 E 0.334 1706.74 3535.35 54.550 59.030 2711.29 2783.42 838.42 N 1590.01 E 6000893.75 N 567644.98 E 0.128 1784.47 3631 .45 54.830 58.930 2766.83 2838.96 878.83 N 1657.22 E 6000934.76 N 567711,83 E 0.303 1862.73 3726.33 54.740 59.520 2821.54 2893.67 918.50 N 1723.82 E 6000975.01 N 567778.07 E 0.517 1940.07 3822.60 53.940 59.110 2877.67 2949.80 958.41 N 1791.08 E 6001015.52 N 567844.98 E 0.900 2018.09 22 August, 2003 - 10:22 Page 2 0'4 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-02 MWD Your Ref: AP/500292316900 Job No. AKMW0002589884, Surveyed: 7 August, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3918.30 53.900 59.350 2934.03 3006,16 997.98 N 1857.54 E 6001055.67 N 567911.09 E 0.207 2095.25 4014.77 54.21 0 59.110 2990.65 3062.78 1037.94 N 1924.64 E 6001096.22 N 567977.84 E 0.379 2173,17 4109.86 54.050 58.990 3046.37 3118.50 1077.56 N 1990.73 E 6001136.43 N 568043.57E 0.197 2250.06 4206.07 53.250 59.950 3103.40 3175,53 1116.93 N 2057.47 E 6001176.39 N 568109.96 E 1.156 2327.34 4303.20 53.730 61.670 3161.19 3233.32 1155.00N 2125.62 E 6001215.06 N 568177.77 E 1.507 2405.04 \.~- 4399.13 53.480 60.750 3218,11 3290.24 1192.19 N 2193.30 E 6001252.84 N 568245.11 E 0.815 2481.84 4494.86 53.030 59.880 3275.38 3347.51 1230.17 N 2259.94 E 6001291.41 N 568311.42 E 0.867 2558.26 4590.00 52.740 60.480 3332.79 3404.92 1267.90 N 2325.76 E 6001329.72 N 568376.90 E 0.588 2633,85 4685.85 51.810 60.170 3391.44 3463.57 1305.43 N 2391.63 E 6001367.83 N 568442.44 E 1.003 2709.37 4782.17 50.790 61.120 3451.66 3523.79 1342.28 N 2457.14 E 6001405.27 N 568507.62 E 1.309 2784.21 4877.66 51.410 57.350 3511.64 3583,77 1380.29 N 2520.97 E 6001443.84 N 568571.11 E 3.140 2858.32 4973.89 52.390 55.290 3571.02 3643.15 1422.29 N 2583.98 E 6001486.39 N 568633.74 E 1.968 2934.03 5071.87 50.630 53.440 3632.00 3704.13 1466.96 N 2646.31 E 6001531.61 N 568695.68 E 2.326 3010.70 5168.22 49.540 53.840 3693.82 3765.95 1510.77 N 2705.82 E 6001575.94 N 568754.80 E 1.175 3084.57 5263.90 48.070 50.820 3756.85 3828.98 1554.74 N 2762.80 E 6001620.42 N 568811.39 E 2.828 3156.45 5360.14 45.870 48.390 3822.52 3894.65 1600.30 N 2816.39 E 6001666.45 N 568864.57 E 2.938 3~26.45 5456.65 43.550 44.31 0 3891.12 3963.25 1647.11 N 2865.53 E 6001713.69 N 568913.30 E 3.823 3293.49 5552.34 39.700 35.300 3962.70 4034.83 1695.70 N 2906.27 E 6001762.64 N 568953.61 E 7.429 3354.65 5648.28 37.870 29.390 4037.51 4109.64 1746.39 N 2938.44 E 6001813.61 N 568985.33 E 4.303 3409.96 5743.30 36.600 22.050 4113.19 4185.32 1798.08 N 2963.40 E 6001865.52 N 569009.83 E 4.859 3459.92 5839.36 35.880 17.550 4190.68 4262.81 1851.47 N 2982.64 E 6001919.08 N 569028.60 E 2.868 3506.14 5934.42 35.590 16.860 4267.85 4339.98 1904.51 N 2999.07 E 6001972.26 N 569044.55 E 0.522 3549,84 6030.85 35.090 17.370 4346.51 4418.64 1957.82 N 3015.48 E 6002025.71 N 569060.49 E 0.602 3593.68 6128.09 35.050 18.020 4426.09 4498.22 2011.04 N 3032.46 E 6002079.09 N 569077.00 E 0.386 3637.95 6169.51 35.080 18.780 4460.00 4532.13 2033.62 N 3039.97 E 6002101.73 N 569084.32 E 1.057 3656,98 ~ 6235.00 35.080 18.780 4513.59 4585.72 2069.26 N 3052.09 E 6002137.47 N 569096.12 E 0.000 3687.24 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 55.290° (True). Magnetic Declination at Surface is 25.4200(05-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 6235.00ft., 22 August, 2003 - 10:22 Page 3 of4 Dri/lQuest 3.03.02.005 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-D2 MWD Your Ref: API 500292316900 Job No. AKMWOO02589884, Surveyed: 7 August, 2003 The Bottom Hole Displacement is 3687.42ft., in the Direction of 55,863° (True). Comments / \..~ Measured Depth (ft) 6235.00 4585.72 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 2069.26 N 3052.09 E Projected Survey Survey tool program for MPS-02 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 546.72 0.00 546.34 22 August, 2003 w 10:22 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 546.72 6235.00 546.34 Tolerable Gyro (MPS-02 Gyro) 4585.72 MWD Magnetic (MPS-02 MWD) Page 4 of4 BPXA ~ .) ~ DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS_02 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~~~.~ ') ð03- J d-1' 23-Aug-03 RECEIVED AUG 2 9 2003 A!aska OH 8: Gas Cone. Gommi38ion AnchOfP!ge Sperry-Sun DrillîngServices "- MilnePo;ntUnit BPXA Milne·PdintMPS MP$·02;Gyro Job Ho. AKF02589884, Surveyed: 7 August, 2003 Survey 'Report 22 August, 2003 Your Ref: API500Z92316900 Surface Coordinates: 6000041.30 H, 566062.45 E (70024' 37.9759" H, 149027'43.4366" W) Grid Coordinate System: HAD27 Ala~ka State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1000041.30 H, 66062.45 E (Grid) Surface Coordinates relative to Structure: 68.80 H, 281.95 W (True) Kelly Bushing: 72. 13ft above Mean Sea Level Elevation relative to Project V Reference: 72.13ft Elevation relative to Structure: 72. 13ft sr"'-'''Y-SLJr1 D A ILL IN GS EA V I c: E S A Halliburton Company DEFNTIVE, -- -- Survey Ref: svy1242 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -72.13 0.00 186.36 0.400 34.000 114.23 186.36 276.38 1.200 76.000 204.24 276.37 366.67 2.500 77.000 294.48 366.61 455,73 3.300 76.000 383.43 455.56 ....... 546.72 4.400 78.000 474.21 546.34 Sperry-Sun Drlll¡11gServices Survey Report for Milne Point MPS - MPS-02 Gyro Your Ref: API 500292316900 Job No. AKF02589884, Surveyed: 7 August, 2003 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 0.00 N O.OOE 6000041.30 N 566062.45 E 0.00 Tolerable Gyro 0.54 N 0.36E 6000041.84 N 566062.81 E 0.215 0.61 1.03 N 1.45 E 6000042.34 N 566063.89 E 1.046 1.78 1.70 N 4.29E 6000043.04 N 566066.73 E 1.440 4.49 2.76N a.67E 6000044.13 N 566071.10 E 0.900 8.70 4.12 N 14.63 E 6000045.55 N 566077.04 E 1.218 14.37 '- All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 55.290° (True). Magnetic Declination at Surface is 25.4200(05-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 546.72ft., The Bottom Hole Displacement is 15,19ft., in the Direction of 74.282° (True). Survey tool prOflram for MPS-02 Gyro /, From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 546.72 546.34 Tolerable Gyro '-" 22 August, 2003 - 10:15 Page 20'2 DrillQuest 3.03.02.005 ) ) d03"- /~7- ) /900 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 03, 2003 RE: MWD Fonnation Evaluation Logs NlPS-02, AK-MW-2589884 1 LIS fonnatted Disc with verification listing. API#: 50-029-23169-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~~ö \J"" ... iV..... ~ '- ~CÙ:::>..~/l/ \. R~ECE'VED SEP 1 6 2003 ~~~~ . ..'" ....\ . , ."'. .1' ,.. l"\'ìì~~iÜr.1I'II AJaSKf\. tF.¡ ~~. G8i~ \.iorm. win¡! ¡"'~iV ij Anœorane 12. Distance to nearest property line 13. Distance to nearest well ADL 380109, 3116' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' / Maximum Hole Angle 18. Casing Program S 'f'cat'on Size pecl I I S Casina WeiÇJht Grade CouDlina 20" 92# H-40 Welded 9-5/8" 40# L-80 BTC 7" 26# L -80 BTC Hole 42" 12-1/4" 8-1/2" ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMrtSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil B Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380110 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-02i 9. Approximate spud date 08/01/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 / 6331' MD / 4662' TVD / o 17. Anticipated pressure {s~e 20 AAC 25.035 (e) (2)} / 54 / Maximum surface 1448 psig, At total depth (TVD) 4142' / 1863 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 112' 112' Surface Surface 2936' 2442' Surface Surface 6331' 4662' k ~/:}d· 1 a. Type of work B Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location· of well at su rface x = 566062, Y = 6000041 3372' NSL;4729' WEL, SEC. 07, T12N, R11 E, UM _ At top of productive interval x = 569007, Y = 6001906 5209' NSL, 1760'WEL, SEC. 07, T12N, R11E, UM At total depth x = 569107, Y = 6002191 213' NSL, 1655' WEL, SEC. 06, T12N, R11E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 LenÇJth 112' 2936' 6331' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 457 sx PF 'L', 190 sx Class 'G' 310 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured true vertical Approved By Form 10-401 Rev. 12-01-85 B Filing Fee D Property Plat 0 BOP Sketch 0 Diverter'Sketch BDrilling Program B Drilling Fluid Program D Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report B 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Sandra Stewman, 564-4750 ~ 21. I hereby certify that the ~ing is ~n~ CO'J~~~hetz~t of my ~nowl~~ge . Signed Pat Archey ,~('~~~~:;;.:=gEngt~eer ;!", Date /-/7-03 Permit Number 7 API Number 3/( CJ Dó APproz. I Qa~.. "7 See cover letter 2..D3 -/2- 50- 02-e; --:2-, Co I ' /} }¡ \j( .~ for other requirements Conditions of Approval: Samples Required 0 Yes ~NO Mud Log Re uireö 0 Yes BfNo Hydrogen Sulfide Measures 0 Yes Øo Directional Survey Required ~es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: ~s-aC).-Q~~ ~\? \.t__~ \- , V\. \ \~ '-~~~,,\- <; ~~ \~,~ \ 0" , ung,naf51g~ _ by orde~ of ~ ~ I Sarah Palin corr]'sR' n~rG I r tfÄormission Date -1 ~ ~~/(i' .7 \j ~ Su mlt In Tnpllcate J _ ~ I 20. Attachments ) ) Schrader Blu. Pad ProQram MPS-02i Permit IWell Name: I MPS-02i Drill and Complete Program Summary I Type of Well (service I producer I injector): Injector NB, OA, OB /' Surface Location: 1901' FNLj3371I FSL],' 4728IFEL:(521 FWL), SEC. 07, T12N, R11E . X=566062.l1.5 Y=6000041.3 / Target Start Location: 2081 FNL, (50701 FSL), 18241 FEL, (2949' FWL), SEC. 07, T12N, R11 E "NB" X=568943.99 Y=6001766.84 Z=4022 TVD Target Start Location: 105' FNL, (5173' FSL), 17731 FEL, (3000' FWL), SEC. 07, T12N, R11 E "OA" X=568993.8 Y=6001870.0 Z=4177 TVD Target Start Location: 691 FNL, (5209' FSL);'1760' FEL((3013' FWL), SEC. 07, T12N, R11 E /' "OB" X=569006.6 Y=6001906.3 Z=4, 193 TVDss Bottom Hole Location 50651 FNL, (213' FSL);16551 FEL,/(3116' FWL), SEC. 06, T12N, R11E/ X=5691 07.3 Y=6002190.72 Z=4622 TVD I AFE Number: I TBD I Rig: I Doyon 14 1 I Estimated Start Date: I 1 AUG 2003 1 Operating days to complete: I. 8.7 I 1 MD: 16331 /1 1 TVD: 146621 I Max Inc: 154 I I KOP: 1300 I I KBE: 172.0 I I Well Design (conventional, slimhole, etc.): I Conventional Grass Roots Water Injector ··r I Objective: 1 Schrader NB, OA, OB Sand 1 Mud Program 12.25-in Surface Hole Mud Properties: Density (ppg) Funnel visc YP HTHP 8.8 - 9.2 75 -150 25 - 60 N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 6.5 8.5-in Intermediate Hole Mud Properties: Density (ppg) PV YP HTHP 8.9-9.2 10-20 20-28 N/A LCM Restrictions: None / Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.0 < 8 < 6.5 1 <6~J ~ ~<t-tlf1 ~f:t) ) Schrader Bluff S-. ) ProQram MPS-02i Permit Cement Pro~ram Casing 9.625-in 40-lb/ft L-80 BTC surface casing Size Basis 175% excess over gauge hole in permafrost interval. 40% excess over gauge hole below permafrost. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 413-bbl Spacer ,50-bbl 10.3-lb/gal un-viscosified Alpha spacer Lead 338-bbl, 457-sx 10.7-lb/gal Permafrost L - 4.15 ffS/sx (cement to surface) Tail 39-bbl, 190-sx 15.8-lb/gal Premium G - 1.15 ft::i/sx of tail at Temp BHST ::= 55°F from SOR, BHCT 60°F estimated by Halliburton Casing Size Basis 7.0-in 26-lb/ft L-80 BTC intermediate casing Top of lead cement 500-ft above top of Ugnu-sand. 40% excess over gauge. Total Cement Wash 20-bbl Water Vol: 57-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Lead 64-bbl, 310-sx 15.8-lb/gal Premium G - 1.15 ffS/sx of tai I at 4325-ft Temp BHST ::= 80°F from SOR, BHCT 70°F estimated by Halliburton Evaluation Program 12.25-in Hole Section: Open Hole: MWD/GRlRES/ IFRlCASANDRA Photo Gyro to 1,1 OO-ft None Cased Hole: ~n Hole Section: " Open Hole: MWD/GRlRES/CNLlCDL ,.- IFRlCASANDRA Cased Hole: SCMT 2 Formation Markers Formation Tops Base Permafrost TUZC NA NB NC NE NF Top OA Base OA Top OB Base OB * Based on 88 depths MDrkb (ft) 1966 4825 5506 5545 5595 5621 5695 5738 5774 5805 5835 ) TVDrkb (ft) 1822 3532 3992 4022 4062 4082 4142 4177 4092 4232 4257 Schrader Bluff s-.) ProQram MPS-02i Permit ~ Xh Pore Pressure Estimated EMW (psi) (Ib/gal)* 8.65 8.65 8.65 8.65 8.65 8.65 8.0 8.0 8.0 8.0 1588 1795 1809 1827 1836 1863 1737 1702 1760 1770 CasinqlTubinp PrOQram Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. M D / TVDrkb M D / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' 12.25 9.625 40# L-80 BTC 2,936' 0' 2,936' / 2,442' 8.5-in 7.0-in 26# L-80 BTC 6,331' 0' 6,331' / 4,662' * The 20-in conductors are insulated! Recommended Bit proqram BHA Hole Size Depth (MD) Bit Type 1 12.25-in 0' - 2,936' 2 8.5-in 2,936' - TD Smith FGXiCPS Smith FGS+ Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1 -1 0 3 ) Well Control: Schrader Bluff S-. ) Program MPS-02i Permit Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity test: · Kick tolerance: · Planned completion fluid: / 1,863-psi @ 4142-ft TVD - Top of "DB" 1,448-psi @ surface / (Based on BHP and a full column of gas from TD @ O.1-psi/ft~ <;f5/.. Jo,< 3,500-psl. b ~~ An FIT to 11.5-lb/gal will be made on the~ casing 'I)') shoe. 52.8-bbl with 8.9-lb/gal mud and FIT of 11.5-lb/gal @ 9.625-in casing shoe. 9.7-lb/gal brine I 7.0-lb/gal Diesel (1 ,800-ft MD) Drilling Hazards & Contingencies: Hydrates . Hydrates have not yet been seen on S pad, but have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the permafrost (+1- 1 ,800-ft TVDss) but may be present in shallower SV sands and also as deep as 3,OOO-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. · Watch out for deeper gravels below the permafrost or gravels that calve off within the permafrost and tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past, several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. We do not expect losses while drilling this well. · MPS-27: Lost returns cementing 7.0-in casing at approx. 800-ft MD. SuccessfuI1.0-in top job. · MPS-21: Lost returns cementing 7.0-in casing. Used TAM port collar at 1 ,OOO-ft with still no returns. SuccessfuI1.0-in top job. · H-06 (1995): Lost 100-bbl running 9-5/8" casing, good returns during cementing except no returns for last 20-bbl, contaminated cement to surface, cement 12 ft down, no top job. · H-05 (1995): Lost returns drilling at 5,360-ft (3,700-ft TVD), 40-bph to keep full, treated wi LCM pills for two days, total losses 838-bbl, made hole opener run with some continued losses. · H-05 (1995): Ran 9-5/8" casing, lost 46-bbl conditioning mud. · H-07 (1995): Lost 50-bbl running 9-5/8" casing. 4 ) Schrader Bluff Sa,) PrOQram MPS-02i Permit · E-24 (1998): Made hole opener run, worked tight spots 1965, 2620, 3465, 5900 and 6000, lost 72-bbl while circulating. · H-08A (1997): Had some minor losses while running 4-1/2" liner. · Follow the LOST CIRCULATION DECISION MATRIX in the well program if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be under-pressured (8.0 Ib/gal EMW). In ./ this well, the Schrader Bluff formation will be drilled with 8.9 to 9.2-lb/gal mud. · Flow-check the well when the reservoir is entered. Pad Data Sheet · Please read the MPU S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Free Gas may be encountered below the Upper Ugnu. Faults · None. Hydrogen Sulfide · Milne Point S-Pad is not designated as an H2S Pad. Anti-collision Issues · None. 5 ) Schrader Bluff S-, ) ProQram MPS-02i Permit DRILL & COMPLETION PROCEDURE DrillinQ 1. MIRU Doyon 14, NU diverter. 2. Drill 12.25-in hole to surface casing point as per directional plan. 3. Rig up and run 9.625-in 40-lb/ft, L-80, ST&C casing and cement in place. 4. ND diverter. NU SOPE. 5. Drill 8.5-in hole to TD as per directional plan. 6. Rig up and run 7.0-in 26-lb/ft, L-80, ST&C casing and cement in place. 7. Test casing to 3,500-psi. 8. Perforate well in OS, OA, NS sand. 9. Run 3.5-in completion. 10. Test packer to 3500-psi 11. Install tubing head and Christmas tree. 12. RDMO Doyon 14. Spinner survey and SCMT log to be done after rig moves off location. 6 ) BP KW A Planning Report MAP Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M Pt S Pad Plan MPS-02 Plan MPS-02 Date: 6/19/2003 Time: 10:31 :04 Page: Co-ordinate(NE) Reference: Well: Plan MPS-02, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (0.00N,0.00E,55.29Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt S Pad ') Alaska, Zone 4 Well Centre BGGM2002 Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: Plan MPS-02 Slot Name: Well Position: +N/-S 65.59 ft Northing: 6000041.07 ft Latitude: 70 24 37.974 N +E/-W -282.17 ft Easting : 566062.29 ft Longitude: 149 27 43.441 W Position Uncertainty: 0.00 ft Wellpath: Plan MPS-02 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57460 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 72.00 ft Plan: MPS-02 wp07 New MPS-02 hitting 02 Target ( not 10) Principal: Yes Casing Points Hole Size Name in 2936.89 2442.00 9.625 12.250 95/8" 6331.42 4662.88 7,000 8.500 7" Formations MD TVD Formations ft ft 1966.79 1822.00 BPRF 4825.68 3532,00 TUZC 5279.89 3822.00 TUZB 5362.18 3882.00 TUBL 5506.97 3992.00 SBF2-NA 5545.35 4022.00 SBF1-NB 5595.94 4062.00 SBE4-NC 5621.00 4082.00 SBE2-NE 5695.37 4142.00 SBE1-NF 5738.28 4177.00 TSBD-OA 5774.90 4207.00 TSBC 5805.42 4232.00 TSBB-OB 5835.94 4257.00 SBA5 (base OB) 6098.40 4472.00 TOBD 6177.75 4537.00 BOBD Date Composed: Version: Tied-to: Lithology Well Ref. Point 0.00 ft Mean Sea Level 26.28 deg 80.78 deg Direction deg 55.29 3/13/2003 28 From Well Ref. Point Dip Angle deg 0.00 0.00 0.00 0.00 0,00 0.00 0,00 0.00 0,00 0.00 0.00 0.00 0,00 0.00 0.00 Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0,00 0.00 0.00 ') ) BP KW A Planning Report MAP Compan)': BP Amoco Time: 10:31 :04 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-02, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-02 Section (\'S) Reference: Well (0.00N,0.00E,55.29Azi) Wellpath: Plan MPS-02 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude ----> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Eastlng Deg Min Sec Deg Min Sec Dip. Dir. Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/10OO deg/1000 deg 33.00 0.00 0.00 33.00 0.00 0,00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300,00 0.00 0.00 0.00 0.00 0.00 0.00 500,00 3.00 90.00 499.91 0.00 5.23 1.50 1.50 0.00 90.00 1439,92 31.00 70.00 1390.10 84.50 262.50 3,00 2.98 -2.13 338.11 1778.70 36.00 61.69 1672.66 161.64 432.33 2.00 1.48 -2.45 313,94 1875.50 37.94 61.69 1750.00 189.25 483.58 2.00 2.00 0.00 0.00 2030.18 37.94 61.69 1872.00 234,35 567.30 0.00 0,00 0.00 0,00 2452.14 54.75 59.69 2162.26 383.91 832.16 4.00 3.99 -0.47 -5.64 4901.43 54.75 59.69 3575,72 1393.48 2558.98 0,00 0.00 0.00 0.00 5740.72 35.00 20.00 4179.00 1804.46 2948.36 4.00 -2.35 -4.73 -138.52 MPS-02 T1 5860.35 35.00 20.00 4277,00 1868.94 2971.83 0.00 0,00 0.00 0.00 6010.35 35.00 20.00 4399.87 1949.79 3001.26 0.00 0.00 0.00 0.00 6181.42 35.00 20,00 4540,00 2041.99 3034.82 0.00 0,00 0.00 0.00 6331 .42 35.00 20.00 4662.87 2122.83 3064.24 0.00 0.00 0.00 0.00 Survey Inel Azilri TVD Sys TVD Tool/Comment ft deg deg ft ft ft 33,00 0.00 0.00 33.00 -39.00 6000041.07 566062.29 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 6000041.07 566062.29 0.00 CB-GYRO-SS 200.00 0.00 0.00 200,00 128.00 6000041.07 566062.29 0.00 CB-GYRO-SS 300.00 0.00 0.00/ 300.00 228.00 6000041.07 566062.29 0.00 CB-GYRO-SS 400.00 1.50 90.00 399.99 327.99 6000041.08 566063.60 1.08 CB-GYRO-SS 500.00 3,00 90,00 499,91 427,91 6000041.12 566067,52 4,30 1.50 0.00 CB-GYRO-SS 600.00 5.89 79.04 599.60 527.60 6000042.16 566075.17 11,15 3.00 338.11 CB-GYRO-SS 700.00 8.85 75.34 698.76 626.76 6000045.19 566087.63 23,08 3,00 349.04 CB-GYRO-SS 800.00 11.84 73.48 797.13 725.13 6000050.21 566104.87 40,06 3.00 352.72 CB-GYRO-SS 900.00 14.83 72.37 894.42 822.42 6000057.20 566126.83 62.04 3.00 354.54 MWD+IFR+MS 1000.00 17.82 71.62 990.38 918.38 6000066.14 566153.47 88.95 3.00 355,63 MWD+IFR+MS 1100.00 20.81 71,08 1084.74 1012.74 6000077.00 566184.71 120.74 3.00 356.34 MWD+IFR+MS 1200.00 23.81 70.67 1177.24 1105.24 6000089.76 566220.45 157.30 3.00 356.85 MWD+IFR+MS 1300,00 26,81 70,35 1267.64 1195.64 6000104.38 566260.61 198.55 3.00 357.23 MWD+IFR+MS 1400,00 29,80 70.09 1355,67 1283.67 6000120.82 566305.08 244,36 3.00 357.52 MWD+IFR+MS 1439.92 31.00 70.00 1390.10 1318.10 6000127.88 566324,00 263.89 3.00 357.75 MWD+IFR+MS 1500.00 31.84 68.36 1441.37 1369,37 6000139.27 566353.17 294.30 2.00 313,94 MWD+IFR+MS 1600.00 33.29 65.80 1525.65 1453.65 6000160.69 566402.54 346.98 2.00 315.34 MWD+IFR+MS 1700.00 34.79 63.43 1608.51 1536.51 6000185,15 566452.88 402.22 2.00 317.50 MWD+IFR+MS 1778.70 36.00 61,69 1672.66 1600.66 6000206.51 566493.13 447.43 2.00 319.46 MWD+IFR+MS 1800.00 36.43 61.69 1689.85 1617.85 6000212.58 566504,16 459.94 2,00 0.00 MWD+IFR+MS 1875.50 37.94 61.69 1750.00 1678.00 6000234,57 566544,13 505.28 2.00 0.00 MWD+IFR+MS 1900.00 37,94 61,69 1769.32 1697,32 6000241.83 566557,32 520.25 0,00 180.00 MWD+IFR+MS 2000.00 37.94 61.69 1848.19 1776.19 6000271.46 566611.18 581,34 0.00 180.00 MWD+IFR+MS 2030.18 37,94 61.69 1872.00 1800.00 6000280.40 566627.44 599.78 0.00 180,00 MWD+IFR+MS 2100.00 40.72 61.27 1926.00 1854.00 6000301.87 566666,12 643.76 4.00 354.36 MWD+IFR+MS 2200.00 44.70 60.74 1999.47 1927.47 6000335.27 566725,13 711.24 4,00 354.69 MWD+IFR+MS 2300.00 48.69 60.29 2068.05 1996.05 6000371.65 566788,13 783.69 4.00 355.07 MWD+IFR+MS 2400,00 52.67 59.88 2131.40 2059.40 6000410,81 566854.81 860.77 4.00 355,39 MWD+IFR+MS 2452.14 54.75 59.69 2162,26 2090.26 6000432.29 566890.94 902.67 4,00 355.64 MWD+IFR+MS 2500.00 54,75 59,69 2189.87 2117,87 6000452,31 566924.50 941.63 0.00 180.00 MWD+IFR+MS 2600.00 54.75 59.69 2247.58 2175.58 6000494.14 566994.63 1023,06 0.00 180.00 MWD+IFR+MS ) ) BP KW A Planning Report MAP COl11þany: BP Amoc:Ö Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-02, True Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-02 Section (YS) Reference: Well (0.00N,O.00E,55.29Azi) Wellpath: Plan MPS-02 Survey Calculation Method: Minimum Curvature Db: Oracle Survey 2700.00 54.75 59.69 2305.29 2233.29 6000535.98 567064.76 1104.49 0,00 180.00 MWD+IFR+MS 2800.00 54.75 59.69 2363.00 2291.00 6000577,82 567134.89 1185.92 0.00 180.00 MWD+IFR+MS 2900.00 54.75 59.69 2420.71 2348.71 6000619.65 567205.02 1267.34 0.00 180.00 MWD+IFR+MS 3000.00 54.75 59.69 2478.42 2406.42 6000661.49 567275.15 1348.77 0.00 180.00 MWD+IFR+MS 3100.00 54.75 59.69 2536.13 2464.13 6000703,33 567345.27 1430,20 0.00 180.00 MWD+IFR+MS 3200.00 54.75 59,69 2593.84 2521.84 6000745.17 567415.40 1511.62 0.00 180.00 MWD+IFR+MS 3300.00 54.75 59.69 2651,55 2579.55 6000787.00 567485.53 1593.05 0,00 180.00 MWD+IFR+MS 3400.00 54.75 59.69 2709.26 2637.26 6000828,84 567555.66 1674.48 0,00 180.00 MWD+IFR+MS 3500.00 54.75 59.69 2766,96 2694.96 6000870.68 567625.79 1755.91 0.00 180.00 MWD+IFR+MS 3600.00 54.75 59.69 2824.67 2752.67 6000912.51 567695.92 1837.33 0.00 180.00 MWD+IFR+MS 3700.00 54.75 59.69 2882.38 2810.38 6000954.35 567766,05 1918,76 0.00 180.00 MWD+IFR+MS 3800.00 54.75 59.69 2940,09 2868.09 6000996.19 567836.18 2000.19 0.00 180.00 MWD+IFR+MS 3900.00 54.75 59.69 2997.80 2925.80 6001038,02 567906.31 2081.61 0.00 180.00 MWD+IFR+MS 4000.00 54.75 59.69 3055.51 2983.51 6001079,86 567976.43 2163,04 0,00 180.00 MWD+IFR+MS 4100.00 54.75 59.69 3113.22 3041.22 6001121.70 568046.56 2244.47 0.00 180,00 MWD+IFR+MS 4200.00 54.75 59.69 3170.93 3098.93 6001163.54 568116.69 2325.90 0.00 180.00 MWD+IFR+MS 4300.00 54.75 59.69 3228.64 3156.64 6001205.37 568186.82 2407.32 0.00 180.00 MWD+IFR+MS 4400.00 54.75 59.69 3286,35 3214.35 6001247.21 568256,95 2488.75 0.00 180,00 MWD+IFR+MS 4500.00 54.75 59.69 3344.06 3272.06 6001289.05 568327.08 2570.18 0.00 180.00 MWD+IFR+MS 4600,00 54.75 59.69 3401.76 3329.76 6001330.88 568397.21 2651.61 0.00 180.00 MWD+IFR+MS 4700.00 54.75 59.69 3459.4 7 3387.47 6001372.72 568467.34 2733.03 0.00 180.00 MWD+IFR+MS 4800.00 54.75 59.69 3517.18 3445.18 6001414.56 568537.47 2814.46 0.00 180.00 MWD+IFR+MS 4901.43 54.75 59.69 3575.72 3503.72 6001456.99 568608.60 2897.05 0.00 180.00 MWD+IFR+MS 5000.00 51.84 56.37 3634.63 3562.63 6001499.38 568675.26 2975.96 4.00 221 .48 MWD+IFR+MS 5100.00 49.00 52.72 3698.35 3626.35 6001544.57 568737.64 3053.00 4.00 223.47 MWD+IFR+MS 5200.00 46.27 48.75 3765.74 3693.74 6001591.77 568794.44 3126.62 4,00 225.79 MWD+IFR+MS 5300.00 43.70 44.42 3836.48 3764.48 6001640.73 568845.37 3196.48 4.00 228.47 MWD+IFR+MS 5400.00 41.31 39.67 3910.21 3838.21 6001691,23 568890.19 3262.22 4.00 231.53 MWD+IFR+MS 5500.00 39.13 34.48 3986,59 3914,59 6001743.00 568928.67 3323.52 4,00 235.03 MWD+IFR+MS 5600,00 37.20 28.80 4065.23 3993.23 6001795.81 568960.64 3380.10 4.00 239.01 MWD+IFR+MS 5700.00 35.57 22.64 4145.76 4073.76 6001849.38 568985.94 3431.67 4.00 243.47 MWD+IFR+MS 5740,72 35.00 20.00 4179.00 4107.00 6001871.36 568994.30 3451,17 4.00 248.43 MWD+IFR+MS 5800.00 35.00 20.00 4227.56 4155.56 6001903.41 569005.65 3478.93 0.00 0.00 MWD+IFR+MS 5860.35 35,00 20.00 4277.00 4205.00 6001936.04 569017,20 3507.19 0.00 0.00 MWD+IFR+MS 5900.00 35.00 20.00 4309.48 4237.48 6001957.48 569024.78 3525.75 0.00 0.00 MWD+IFR+MS 6000.00 35.00 20,00 4391.39 4319.39 6002011.54 569043.92 3572.57 0.00 0.00 MWD+IFR+MS 6010.35 35.00 20.00 4399.87 4327.87 6002017.14 569045.90 3577 .42 0.00 0.00 MWD+IFR+MS 6100.00 35.00 20.00 4473.31 4401.31 6002065.61 569'063.06 3619.39 0.00 0.00 MWD+IFR+MS 6181.42 35.00 20,00 4540,00 4468.00 6002109.62 569078.64 3657.51 0.00 0.00 MWD+IFR+MS 6200.00 35.00 20,00 4555,22 4483.22 6002119,67 569082,20 3666.21 0.00 0.00 MWD+IFR+MS 6300,00 35.00 20.00 4637.14 4565.14 6002173.74 569101,34 3713.03 0.00 0.00 MWD+IFR+MS 6331.42 35.00 20.00 4662,87 4590.87 6002190.72 569107.35 3727.74 0,00 0.00 MWD+IFR+MS Tool CB-GYRO-S: Mlvrr-IFR~MS SURVEY PROGRAM Depth Fm Depth To Su!yey,pJan 33.00 900.00 PJarmed: MPS-02 "p07 V28 900.00 6331.42 PJarmed: MPS-02 "p07 V28 COMPANY DETAILS BP Amoco Ûllcularion Method: Mìnimum ClU'o'a!Ure Error System: ISCWSA Scan Method: Trav Cylinder North Erroc Surfuœ: ElJip<ic3l ~ Ca.;ng Warning Method: Rules Based ANTI-COLLISION SETIINGS Interpolation Method:MD Interval: Depth Range From: 33.00 To: Maximwn Range: 829.84 Reference: Slot N'A Lalitlkk Longitude 70°24'37.974N 14r2T4J..141W WElL IJETMLS Northing l:asling 6000041.07 56606219 ·IOf·W -n2.17 ·N'-S 65.59 N3m: Pl.m Mps· vSec 0.00 0.00 430 263.89 447.43 50518 599.78 902.67 2897.05 3451.17 MPS-02 T1 3507.19 3577.42 365751 3727.74 ....-' --- WELLPA TH DEi All.S PJan MPS-02 72.00n Slarting From TVD 0.00 LEGEND >OOOOOOOOO< p..-fPS..(}] (MPS-I'II M.JI"I .~.... - 1-.IPS-01 (~iPS..Illlll M-II'" ~isk = fo.IPS-01 (MPS-III.'llll M-I1'" Risk p..œs..oJ (tIPS.{I. M J '.' r: ." - p..IPS-03(MPS-t'IL II "'L,.", .lisk f\.(pS..().I (MPS 1'-11 1'1.I Jr··¡ H'.... - MPS..ß4-(MPSJl"H I I'lll M-I1orRisk lI.lPS-04(MPS·u4ll J'II:I ~.I.JlorRisk - p..tpS..().J (MPS·U-Il11. p..,_..", nlsk - l\.IPS-05 (}JPS-lI"q MJ '" ft, ... - l'o-IPS-05 (MPS.JI·L IJ ".1-11'" ['isle ~ MPS..(}S (MPS-II"'("UII MJ1·.. Risk MPS-07 Q.-IPSJI/I MJI'" k.... - lvIPS-09 Q.{PS-II·~I M-II'" rl, ¡.. - t-.IPS-IO (MPS III) M.JI'" "',.l - MPS-Il (MPS III MIl'" Po,'" - MPS-12 {l'o-fPS la' M.JI'" ii, .. - MPS-12(MPS l:lll MJ '" .:i.sk: - MPS-12(MPS l.:i"UII ""bl'. Risk: ~ MPS-I3 (JIÆPS III M..II'" JolI , - }'fPS-lS(MPS I'" M.JI'" rlU. - twlPS-16(MPS 1"1 MJI'" I-l,.~ - lo.fPS-11(1\-fPS 17} M.J¡'" U. k - MPS-I1(MPS 17llJ t!.'.J'''' nisk: - MPS-18(MPS IXI MJI'" k'..L - l-.fPS-18(MPS I,(I"HI' Pl.blc. Risk: - Plan MPS-06 (I"LL,. Pl.U":, ''''"1, Major Risk - Plan MPS..()8 (h.J.i, ".11'":" ......) :'I,iajor Risk - Plan MPS-14 (t"Ln MI'3 I ~), p..iajor Risk - Plan MPS-02 - MPS-02 "p07 SECTION DETAILS +N'-S -E/-W 0.00 0.00 0.00 8450 161.64 18915 23435 383.91 1393.48 18(14.46 1868.94 1949.79 2(141.99 2122.83 S-Pad Dev Origin -E/-W 0.00 Target Origin +NI-S 0.00 DLeg TFac, 0.00 0.00 0.00 0.00 150 90.00 3.00 338.11 2.00 313.94 2.00 0.00 0.00 0.00 4.00 -5.64 0.00 0.00 4.00 -13852 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Rig: Rer. Da!wn: V -Seclion Angle 5519 0.00 0.00 513 26250 43233 48358 56730 832.16 2558.98 294836 2971.83 300116 3034.82 306414 From Colour To MD o 250 250 500 500 ------ 750 750 1000 10UO 1250 1250 - 1500 1500 1750 750 2000 Azi TVD 33.00 0.00 0.00 33.00 300.00 0.00 0.00 300.00 500.00 3.00 90.00 499.91 1439.92 31.00 70.00 1390.10 1778.70 36.00 61.69 1672.66 187550 31.94 61.69 1750.00 2030.18 31.94 61.69 1872.00 2452.14 54.75 59.69 216216 4901.43 54.75 59.69 3575.72 5740.72 35.00 20.00 4179.00 58/~)35 35.00 20.00 4277.00 601035 35.00 20.00 4399.87 6181.42 35.00 20.00 4540.00 6331.42 35.00 20.00 4662.87 90 25.00 6331.42 Plan: MPS-02 wp07 I 3 4 5 6 7 8 9 10 II 12 13 14 í3 00 2~ 270 -160 -150 -100 -100 -125 -125 -so -so -25 -75 -25 -75 -0 - 50 180160 -ISO -160 ') I BP Anticollision Report ) Datè: Page: Reference Site: Reference Well: Reference Wellpath: GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 33,00 to 6331.42 ft Maximum Radius: 829.84 ft Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan MPS-02, True North S-Pad Dev 72.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/29/2001 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 33.00 900.00 Planned: MPS-02 wp07 V28 CB-GYRO-SS Camera based gyro single shots 900.00 6331.42 Planned: MPS-02 wp07 V28 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 2936.89 2442.00 9.625 12.250 95/8" 6331.42 4662,88 7.000 8.500 7" Summary <- Offset Well path -------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt S Pad MPS-01 MPS-01 V4 274.49 275.00 16.00 5.85 10.15 Pass: Major Risk M Pt S Pad MPS-01 MPS-01 L 1 V3 274.49 275.00 16.00 5.72 10,28 Pass: Major Risk M Pt S Pad MPS-01 MPS-01 PB1 V7 274.49 275.00 16.00 5.98 10.02 Pass: Major Risk M Pt S Pad MPS-03 MPS-03 V20 579.18 575.00 16.24 11.29 5.00 Pass: Major Risk M Pt S Pad MPS-03 MPS-03L 1 V9 579,18 575.00 16.24 11.16 5.13 Pass: Major Risk M Pt S Pad MPS-04 MPS-04 V6 349,37 350.00 30.49 8.06 22.43 Pass: Major Risk M Pt S Pad MPS-04 MPS-04L 1 PB1 V12 349.37 350.00 30.49 8.02 22.47 Pass: Major Risk M Pt S Pad MPS-04 MPS-04L 1 PB2 V8 349.37 350.00 30.49 8.02 22.47 Pass: Major Risk M Pt S Pad MPS-04 MPS-04L 1 V3 349.37 350.00 30.49 7.80 22,69 Pass: Major Risk M Pt S Pad MPS-05 MPS-05 V1 428.62 425.00 44.84 8.36 36.49 Pass: Major Risk M Pt S Pad MPS-05 MPS-05L 1 V1 428.62 425.00 44.84 8.23 36,62 Pass: Major Risk M Pt S Pad MPS-05 MPS-05PB1 V2 428,62 425.00 44.84 8.44 36.41 Pass: Major Risk M Pt S Pad MPS-07 MPS-07 V9 519.45 525.00 74.70 9.32 65.43 Pass: Major Risk M Pt S Pad MPS-09 MPS-09 V5 517.18 525.00 106.74 9.30 97.46 Pass: Major Risk M Pt S Pad MPS-10 MPS-10 V14 540.33 550.00 119.53 11.41 108.14 Pass: . Major Risk M Pt S Pad MPS-11 MPS-11 V4 500.00 500,00 135.62 9.71 125.92 Pass: Major Risk M Pt S Pad MPS-12 MPS-12 V4 347,58 350,00 151.19 9.07 142.12 Pass: Major Risk M Pt S Pad MPS-12 MPS-12L 1 V1 347,58 350.00 151.19 8.81 142.38 Pass: Major Risk M Pt S Pad MPS-12 MPS-12PB1 V1 347.58 350.00 151,19 9.03 142.17 Pass: Major Risk M Pt S Pad MPS-13 MPS-13 V6 180,29 175.00 167.07 3,83 163.25 Pass: Major Risk M Pt S Pad MPS-15 MPS-15 V7 370.35 375.00 193.14 7.37 185.77 Pass: Major Risk M Pt S Pad MPS-16 MPS-16 V8 346,30 350.00 211.71 7.23 204.48 Pass: Major Risk M Pt S Pad MPS-17 MPS-17 V7 400.00 400.00 227.03 8,16 218.87 Pass: Major Risk M Pt S Pad MPS-17 MPS-17L 1 V1 400.00 400.00 227.03 8.05 218.98 Pass: Major Risk M Pt S Pad MPS-18 MPS-18 V8 463.85 475.00 240.93 10,70 230.23 Pass: Major Risk M Pt S Pad MPS-18 MPS-18PB1 V9 463.85 475.00 240.93 10.85 230.08 Pass: Major Risk M Pt S Pad Plan MPS-06 Plan MPS-06 V4 Plan: M 373.87 375.00 60.70 9.28 51.42 Pass: Major Risk M Pt S Pad Plan MPS-08 Plan MPS-08 V4 Plan: M 373.32 375.00 90.69 9.32 81.37 Pass: Major Risk M Pt S Pad Plan MPS-14 Plan MPS-14 V3 Plan: M 323,90 325.00 180.50 7.84 172.65 Pass: Major Risk Site: M Pt S Pad Well: MPS-01 Rule Assigned: Major Risk Wellpath: MPS-01 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.70 33.70 34.20 34.20 0,00 0.00 76.77 76,77 7,625 15.07 0,84 14.23 Pass 49.50 49.50 50,00 50.00 0.04 0.01 76.83 76.83 7.625 15.07 1.14 13.93 Pass 74.50 74.50 75.00 75.00 0,10 0.03 77,17 77.17 7.625 15.06 1.62 13.45 Pass 99.50 99.50 100.00 100.00 0.15 0.05 77.82 77.82 7.625 15.05 2.10 12.96 Pass 124.50 124,50 125.00 125.00 0.24 0,07 78.77 78.77 7,625 15,04 2.66 12.38 Pass NB OA OB j j ~ µ ~~ ~ fl 1:j /' ~ ~t :~I $1 ~l ~ .¡ ..- ) ) S-02i Injector Completion Diagram (PROPOSED) ~ Tubing hanger connection 4-1/2" N8CT pin x-over pup 4-1/2" N8CT box X 3-1/2" IBT pin 3-1/2" 9.3# L80 IBT tubing 3-1/2" 'X' nipple (2.813') set at -2200' MD i 9.625-in, 40#, L-80, BTC-M @2936'MD/2442' TVD 3-1/2" 'X' nipple (2.813') set 1 O-ft above PBR 5' of seals 7" x 4-1/2" packer - Baker 8-3 w/1 0' PBR Camco MMG mandrel Camco MMG mandrel 3-1/2" 'X' nipple (2.813') set 10-ft above packer 7" x 4-1/2" packer - Baker 8-3 Camco MMG mandrel Camco MMG mandrel X' nipple (2.813') set 10-ft above packer 7" x 4-1/2" packer - Baker 8-3 'XN' nipple with 2.75" no-go Re-entry guide 7", 26#, L-80, BTC-M @ 6331' MD/4662' TVD/RKB I I 1 r I I h I 1 I r I I r --I I L I I I r 1 I ~ I f¿' i~ J ". / ~tq, __ _T_ _ _ _T_ _ _ _T_ _ _ _T_ J , ~ / .. I NOTES: 1. DATE OF SURVEY: DECEMBER 13 & 15, 2002. 2. REFERENCE FIELD BOOK: MP02-08 PGS. 16-17 & 20-21. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. J ~ ~ ¡; ~ ¡¡ i s i MPS-34t 33 -31i _29i _27 _25 _24i -23 -21i _19i -17 _15i -13i - 11 - 9i __ -7i Ii 5 __ MPS-2.l3 MPS-1 ... ) 28 21 I I ~ 1 I J I I I 1 1 I ~ I I J .l SteT - - -.1- ~ :::::-:-:... 72 T72 I 1 SteT 7' . ':J. R70t T72N. R7ïf- ' . I. I I -1 I -z - I PLAN T ) 15°00'00" GRID' 35 3r ~,32 ~ 1 6 5 4 K-PAU "~~PROJECT3 S-PAD ~ 1.iF'''- 12 ~ \ 8 9 10 MPU S-PAD 11 Ww 13 ~::: 18 œœ LEGEND 14 17 16 15 4- . AS-BUILT CONDUCTOR EXISTING CONDUCTOR VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 15, 2002. LOCATED WITHIN PROTRACTED SEC. 7, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-01 Y=6,OOO,044.65 N= 2,236.68 70°24'38.007" 70.4105578" 38.3' 3,375' FSL X= 566,076.93 E= 6,959.07 149°27'43.011" 149.4619475° 4,714' FEL MPS-02 Y=6,000,041.30 N= 2,237.19 70°24'37.976" 70.4105489° 38.3' 3,372' FSL X= 566,062.45 E= 6,944.21 149°27'43.437" 149.4620658° 4,729' FEL LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-34 Y= 5,999,917.12 N= 2,237.28 70°24'36.795" 70.4102208° 38.0' 3,252' FSL X= 565,598.66 E= 6,464.04 149"27'57.063" 149,4658508° 412' FEL F. ROb' DRAWN: Obp COTTON ~ l~-- CHECKED: AWSON ¡ ~ ~ . DATE: ~ 12/11/02 DRAWING: MILNE POINT UNIT S-PAD SHEET: ~ FRB02 MPS 33-00 i] ¡u~~rnœo JOB NO: SCALE: AS-BUlL T CONDUCTORS r 0 12/17/02 ISSUED FOR INFORMAlION JJC RFA EHQNŒRS NIO LMO SUR\l£'l'OftS WELLS MPS-01, MPS-02 & MPS-34 1 OF 1 80'1 WEST F'fÐI([I) 1.NI[ 1"= 160' "NO. DA ìE REVISION BY CHK __ NJ.!!MA ""'" P055090 DATE 6/9/2003 INVOICE / CREDIT MEMO DESCRIPTION INV# CK060403J PERMIT TO DRILL ~EE THE ATTACHED C..,i:CK is IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ BP EXPLORATION, (ALASKA) INC. D::~JrlOE BAY UNIT ='::; BOX î966'12 ~\CHOHAGE AK 99519-6612 PAY: ,-... TO THE ORDER OF: -~-~ B p ~.. ft '". . . ¡ . ~ ~ .,1'.. ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 GROSS NATIONAL CITY BANK Ashland, Ohio ,....j, ,i'" i....,17 ! DATE 6/9/2003 VENDOR DISCOUNT CHECI< NO. 055090 ---.-.--------------- ¡\lET ------~---- ~ --------------- ---_.--- --. 56-389 412 No.P --.------- --- 055090 CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT ___.____,_ June 9, 2003 *******$100.00******* NOT VALID AFTER 120 DAYS ~'i':!;~~C1,' ·'L.o __~C__~..\:_.! .~:.__ lIDS 5 0 g 0 II- I: 0 ~ 1. 2 0 3 B g 5 I ~ 0 ¡. 2 7 B g b liD ) ) TRANSMIT AL LETTER CHECK· LIST CIRCLE APPROPRlAT:E: LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME pJ p¿{ .:;..~ ð2 L" 2-03-/Z 7 PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) M1JL TI LATERAL (H API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject ,to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent UpOD issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST Company . BP _E>-<PLQB8I1QR{AL8.5K8) JNG_ __ n__ ._.m un._ __n_ _.. PTD#:2010410 Field & Pool MILNE P-ºINI-,_~ÇHRADER BLFF ºLl.~~5140 Initial Classrrype Administration 1 P.ßrmiUee attache.d. . . . . . . . . . _ .. . . . . _ . . . . . . . _ . . . . . . . .. ... Y.ß$ . . . . _ . . 2 .Leas.ß.number .appropriate. . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . Y.ß$ . . . . . . . _ . . 3 .Uni.que weILn.arn.ß.and oumb.er. .... _ . .. .. Y.ßs . _ . _ . . . 4 .WeJUQcat.ßdi.n.a.d.efil1e.d.pool_.. ........... Yes _........... 5 .We.IUQcat.ßçf pr.oper .di.stançe. from driJling Ul1it.b.oul1daIY. . . . . . . . . . . . . Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 .We.IUQcat.ßçf pr.oper .di.stance. from Qthe.r wells. Y.ß$ . . . . . . . . . . . . . . 7 .S.utficiel1t.açreage.ayailable [n.drilJiOg unit. . . . " . .. . . . . . . . .. .. . . . Y.ß$ . . .. . . . . . . . _ . . . . . . . . _ _ . . . . . . _ 8 Jf.d.ßviated, .is. weJlbQre plç¡Ul1cJu.ded . .. . . . . . . . . _ . . . . . . . . . Y.ß$ . . . . . . . . . . . . . . . . . . . . . . . . . 9 .QP!3r.at.or onl~ affected party. .. . Y.ß$ . . . _ 10 .Qper.ator bé!s.apprppr[ate.b.ond i.nJQrçe. _ . . . . . . . . . . . . Y.ß$ ... _ . . _ _ . _ . . . . . . . . . . . . . . . . 11 P.ßrmit c.an Þe i.s$u.ed wHhQut Co.nserva.tiOI1 order. . . . . .. Y.ß$ . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . 12 Permitc.an Þe i.ssued withQut ad.mil1istr:.ati~e.approvaJ . .. . Y.ß$ . . .. . . . . . . . . . . . . . . .. . . . . . . . _ . . . . . . . ~...":) 7/22/2003 13 .C.an permHbe apPJQv.ßd befon~ .15-day. waJt. _ . . . . . . . . . . _ . . . . . . .. Y.ß$ . _ . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . .. ) 14 .We.IUQcat.ßd wi.thil1 area and.strata .autl1ori.zed by.lojec;tipo Ord.ßr # (puUO# in.cPl)1rn.ßot~).{For. Y.ß$ . . . . . .. Ar.ßa lnje.ctio.n.Qrde.r Np.. 1.0~8 . . . . . . . . . .. ...... 15 AJI w.ß I] s. within .1l4.llJiLe .are.a.of reyiew id.ßot[fied (Fpr:. serv.ic.ß .w.e J ol1l~) . . . . . . . . Yes . . prpducti~e.ilJteryaI5 in.all offs.et. we.lIs are .>.1/4. mi.le.from. tbi~ wellbpre, . _ . 16 Pre.-produ.cedi!.ljectQr; .duratio.n.ofpre-:pro.duc;ti0I1I.ß$s.tl1an.3months.(For.ser:vi.cewell.Qn.ly).. No....... _ _.... _.. ..... _. .... _..... ............ 17 .ACMP. ~il1ding .of CQnßi.stency. h.a$ bee.n .issued.for..tbi$ pr.oieçt _ NA . . . . . . . . . . _ . . . . . . . . . . _ . . . . . . . Appr Well Name: MI.L~2_01t-J.LUNJT..s_B_ _.s.:_Q2 _. .... ..__.__.. Program .s..EB___ SER I 1 WI NJ GeoArea 890 Unit 11328 On/Off Shore .Q!l___._ l] o Well bore seg Annular Disposal . - - - ~ .. - .. - - - - - - - - - - - - .. - - - - - - - - - . .. .' - - . - '" .. - - - - - . - - - . .. - - - - ~ - . - - - - - . . - - - - - . .. - - - - - - - - - - - - - - - . .. - - - - ~ - - . - - - . - - - - - - - - _ _ _ _ W _ _ Date - - - ~ - - - - . Engineering __..__,,____.~·_.__n_W." ____ "_'·'W.__ .. ,_ __. _, ___w..______ --.--------------.----.,-------- ,.--..-----..-,.-..-..--- .--.,...-------.- Appr Date T~M 7/22/2003 ~rtV1 ~ ~I;)~ Geology Appr SFD Date 7/22/2003 Geologic Commissioner: 015 ---------..--,--....-,-------,,-..------.-.- _"...~._~_.__....___~___..__.___._.,,_......____ __.__.·w___..._____________ 18 .C.ondu.ctor ::¡tring.prQv[ded _ . . . . . . .. _ . . . _ . . . . . _. . . . . Y.ß$ . . .. . . . _ _ . . . . _ . . . . . . _ . . . . . . _ . _ . . . . . . . . . 19 .S.urfac.e.c;;lsil1g_PJQteGts.QII..knQwn.USQW::¡... _ _ . . . NA . . . . . . . AllaquifeJ::¡ eX~l)1pt.ßd ~Q eFR H7..1.02.(þ)(3) . . . . _ . . . . . . . . . ._ 20 .CMT. vol. adequ.ate.to çircJJlate.on .cOl1d.uçtor. & SUJf.~g . . . . . . . . . Y.ß$ . . . . . . . . . . . 21 .CMT. v.ol adequ.ate.ìo tie-tn JQng .string to.surf csg_ _ _ _ _ _ . _ . . . . . . . . . _ _ _ _ _ . _ . _ . _ NA _ . . . . . . . . . . _ . _ _ _ _ _ _ _ _ . . . _ _ _ . _ . _ _ _ _ _ _ _ _ _ . _ . _ . . . _ _ . _ _ _ _ . _ . . _ _ _ . _ . _ . _ . _ _ _ _ . . _ _ 22 .CMT.will coyer.aU !<oo.w.n_pro.ductiye hQrizQn.s. . . . . . . . . . . . .. . Y.ß$ _ . . . .. . . . . . . . . . . . . . . . . _. . . . . . . 23 .G.asing de.si.gns ad.eqUélte. fpr C,T~ 6&. p-erllJafrost. . _ . . . . Y.ßs . . . . . . . . . . . . . . . _ . . . . _ . . . 24 .A.dequate.tan.kç¡ge.oJ re.serye pit. . . . . . . . . . . . . . . . . . . . . . Y.ßs . Rig is.e.quippe.dwith st.ßel.p[ts. . No. r!;3sewe.pjt.pla!.ll1e.d, All waste t.o.class U well(s).. . 25 Jf.a.re-drill.. l1as_.a. 1.0::40;3 fQr abandonment þe.ßO ;;lPPJQved ... . . NA . . . _ _ . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . 26 Adequate well þore. separation .propo::¡ed, . . . . . . . Y.ßs . ... . . prp~imi.ty analysis pe.rforme.d.. No _close. approach_ issu~s identified.. .Gyro.s .ayailable {or magn.et.ic interl'eral1ce .. 27 Jfdiver:ter reqJJire.d, dQes it me~t. n~guJa.tiOl1s. . . . . . . . . . . . . Y.ßS . . . . . . _ . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . 28 DrilJiog fluid.p-rQgram $c.h~mat[c.&.equipJi$t.adequat.ß. _ . . . . . _ Y.ß$. . . . . . . Expect.BHP.8,0.E;MW.. Planl')e.dmu.dweigl1ts.8,9.-.9,2.p-pg.. . . . . . . . . . . . . . 29 .BOPEs.. d.o .they meet r~guJatiOI1 . Y.ßs 30 .BQPE.pre.s$ ratiog appropriate; .test. to.{pu.t psig in .commel1ts). . . . . Y.ßs . . . . . . . CalcuJa.te.d.MASPH48. psi.. Planned BOP tesì.pressure 35QO.psi... ....... 31 .C.hoke.manifold cQmpJies. w/API.RP-53 (May a4). . . Y.ß$ . . . . . 32 WQrk Will occ.ur wit.hout.operation .sbutdown. . Y~s . 33 .Is presence.o.f H2S gas. p-rob.abl~ _ . . No. . _ 34 Mecha.ni.~I.cPl)djti.on p{ we.lI$ wi.thin AOR yerified (For.s.er.vice Wf31J only) Y.ßs . _ w w ,. . . - - - - - - - - - - - - - - . . NQ wellþores penetrélte the $çhrader I3l!-1ff wi.thil1114 mile of.MPS.-Q2.. . .. __·_______w.__ ___..___,_,___._.___..______~_.___ ~_.____________,______._._..__.._______. _.w·___.·___ _______________ -- -.----'"----------------.-.------.---.--....---- --..------- ------.._----._- -..--.---- __._W__._~.____ 135 136 137 1 138 !39 P.ßrmit. cPn be issu.ed wlo. hydr.ogen. s.ulfide measJJres . D.ata.presf3oted on. Rote.ntial pverpres.sur~zones . .Seism[c.analys.is. Qf shallow gé!szooes . .S.ßaÞedconditioo survey (if Oft'-shpr:.e) _ CQnta.ct nam.elphone.for.we!3kly progress.reRorts [exploratory .only]. . . Yes Y.ß$ . NA. NA. . _ NA. . . Est..pressure [n.reservoir is.8,O. ppg .EMW; will. b.e.drilJe.dwith 8..2.to 9.0 ppg mud. . Date: 7/u/3 Engineering Commissioner: Date Public Commissioner Date ) 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 inlprove the readability of the Well History file and to sim.plify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri_)ing Services LIS Scan Utility ') 803-/87 119 'ðÒ $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 29 10:43:54 2003 Reel Header Service name........... ..LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 03/08/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.. ... .01 Previous Tape Name...... .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-02 500292316900 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 29-AUG-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2589884 T. MCGUIRE E. VAUGHN MWD RUN 2 AK-MW2589884 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 7 12N 11E 3372 4729 MSL 0) .00 72.13 38.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 8.500 9.625 2933.0 :;."j¡ r"" C E' \/E D" . r~(.b !to u # SEP 16 2003 ~~~\"\\~ A¡a~ka æ¡ ~~. GaD Cons. C(}mm¡~,5k1n l~nrlïor~ne REMARKS: ) ) 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., 'DATED 8/22/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 AND 2 REPRESENT WELL MPS-02 WITH API#: 50-029-23169-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6235'MD/4586'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/29 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM RPS RPX FET $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 69.0 112.5 2920.5 2920.5 2920.5 2920.5 2920.5 STOP DEPTH 6196.5 6235.0 6188.5 6188.5 6188.5 6188.5 6188.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- ) ) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 69.0 2940.0 MERGE BASE 2940.0 6235.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69 6235 3152 12333 69 6235 Rap MWD FT/H 10.39 1988.34 423.201 12246 112.5 6235 GR MWD API 4.4 143.95 66.8746 12256 69 6196.5 RPX MWD OHMM 1.62 2000 18.2759 6537 2920.5 6188.5 RPS MWD OHMM 0.06 412.97 16.4907 6537 2920.5 6188.5 RPM MWD OHMM 1.78 2000 19.9917 6537 2920.5 6188.5 RPD MWD OHMM 0.27 2000 23.3021 6537 2920.5 6188.5 FET MWD HOUR 0.04 32.11 0.483563 6537 2920.5 6188.5 First Reading For Entire File......... .69 Last Reading For Entire File.......... .6235 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/08/29 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...... .03/08/29 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ') header data for each bit run in separate files. 1 .5000 START DEPTH 69.0 112.5 STOP DEPTH 2895.0 2940.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 05-AUG-03 Insite 66.37 Memory 2940.0 112.0 2940.0 .0 56.5 TOOL NUMBER 155790 12.250 112.0 Spud Mud 9.60 102.0 8.0 800 9.4 .000 .000 .000 .000 .0 68.0 .0 .0 REMARKS: ') ) $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing........ ............ .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69 2940 1504.5 5743 69 2940 Rap MWD010 FT/H 11.54 1988.34 361.82 5656 112.5 2940 GR MWD010 API 17.02 119.11 61.4944 5653 69 2895 First Reading For Entire File......... .69 Last Reading For Entire File.......... .2940 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation... ....03/08/29 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/08/29 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2895.5 2920.5 2920.5 STOP DEPTH 6196.5 6188.5 6188.5 ~ . RPS RPX FET ROP $ 2920.5 ) 2920.5 2920.5 2940.5 6188.5 6188.5 6188.5 6235.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 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): 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) 07-AUG-03 Insite 66.37 Memory 6235.0 2940.0 6235.0 35.1 55.6 TOOL NUMBER 126027 145654 8.500 2933.0 LSND 9.30 58.0 9.0 300 5.3 2.700 1.940 6.500 4.500 65.0 93.2 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H ) 1 68 4 2 ) GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2895.5 6235 4565.25 6680 2895.5 6235 ROP MWD020 FT/H 10.39 1863.42 475.883 6590 2940.5 6235 GR MWD020 API 4.4 143.95 71.4808 6603 2895.5 6196.5 RPX MWD020 OHMM 1.62 2000 18.2759 6537 2920.5 6188.5 RPS MWD020 OHMM 0.06 412.97 16.4907 6537 2920.5 6188.5 RPM MWD020 OHMM 1.78 2000 19.9917 6537 2920.5 6188.5 RPD MWD020 OHMM 0.27 2000 23.3021 6537 2920.5 6188.5 FET MWD020 HOUR 0.04 32.11 0.483563 6537 2920.5 6188.5 First Reading For Entire File......... .2895.5 Last Reading For Entire File.......... .6235 File Trailer Service name.... ..... ... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/29 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.004 Physical EOF Tape Trailer Service name. ...... ..... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... ...... . UNKNOWN Continuation Number..... .01 Next Tape Name...... .... .UNKNOWN Comments.......... ...... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/08/29 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name....... ........ .UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments......... ....... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
