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201-157
i • BlueCrest Alaska Operating LLC ., , , 1 1 ue est 3301 C Street,Suite 202 Energy Anchorage,AK 99503 (907) 754-9550 September 28, 2015 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, Alaska 99501 SCANNED NOV 0 92015 go- t C./- RE: Hansen l Arfi pplication for Sundry Approval to Install 2 3/8" Coil Velocity String and Obtain a rude Sample—Permit to Drill 207-079 Dear Sirs, BlueCrest Alaska Operating LLC is submitting a coil velocity string installation and short term well test to obtain a clean crude sample proposal for the AOGCC's review and approval for Hansen IAL I.The velocity string is to prevent the well from slugging when we start production. The sample is to obtain an assay for Tesoro refinery for sales dtermination. Estimated date of operation will be one week after approval. Our plan is to: 1. Rig up slick line to pull the BPV,pull the plug at 1144'MD and drift the 4.5"tubing to 16,000'. RD Slick line. 2. Rig up Great Northern Testing equipment to wing valve and place flare according to current and prevailing winds. Initially only well returns will flow through this equipment. 3. Rig up Schlumberger's coil tubing unit. Displace coil with diesel.Run approx. 14,000'of 2 3/8"coil string and hang off on a Baker packer at 2000'. Raise service coil and displace top 2000'of 4.5"tubing with nitrogen. 4. Start flowing well through test equipment to obtain crude sample.As soon as well starts flowing,pull service coil out of hole and rig down. 5. Obtain a clean crude sample and stop flowing the well. 6. Rig down well test equipment and inject all produced liquids back into the well. The flowing of the well should last no more than two days. We anticipate a maximum gas flare of 1.0 MMSCF/D. We will aline our flare downwind of the current wind direction and adjust it as necessary if conditions change. In addition,there is a high probability that the SSSV ball valve is not present. Therefore, we will need a variance to flow the well for three days without a SSSV. We will have a remote on the SSV and the well will be monitored at all times while flowing.All operations will be during daylight hours. We have attached various schematics and detailed procedure to help explain our proposal. Please feel free to contact me if you have any questions. R ards, Randy Frazier Drilling Manager BlueCrest Alaska Operating LLC Phone(907)250-4420 • • Hansen 1-AL1 Velocity String Running Procedure V.1.6 9/28/15 1. Pre job safety meetings will be held w/all crews and company representatives prior to all operations below. Include personnel from all Simops going on at the pad. Discuss dropped objects,working with pressure,working at heights and safe zones if well control issues should arise. Please check each other for PPE required. Safety is the number one consideration and after that we will think about operational efficiency. 2. RU Pollard Wireline crane or other available crane to remove wellhouse if it is still in place. 3. Remove wood foundation of wellhouse if necessary to spot equipment, if not leave foundation in place and level area cellar area as required. 4. Place Herculite or acceptable substitute on ground around unit as required. 5. Grating should be in place over cellar. 6. RU control panel if required for SSV and SSSV. a. Make sure at this point that well valve equipment will allow concurrent flow testing along with SLB CT unit and SLB BOP rigging up and down. If not make changes as required prior to SLB unit arrival and rig up. b. Double barrier required during rig up and rig down of SLB unit(master and swab valves on tree). 7. RU Pollard W/L Services. 8. FMC to pull BPV. (Pollard will assist if necessary.) 9. Rig up Great Northern Testers(Tanks to be bermed as required.) Be prepared to flow test well ASAP after N2 blowdown at 2000'prior to SLB POH w/CT. 10. Blank off SSSV lines if not already blanked off. 11. Pollard pull HES SSSV at 1004' MD if WL valve is in place. If not go to step 12. 12. Pollard pull AD-2 D&D packoff at 1144' MD and related equipment. Should require 3 separate runs. 13. Pollard W/L RIH w/3.70" (largest ID of velocity string equipment to RIH) HES RN No Go nipple at 15929 MD. Pass thru MD IDs as follows: A. SSSV at 1004'w/3.813" bore B. GLM at 13996 in schematic as 3.958" (last schematic says dummy valve installed) C. Baker SCMU Sliding Sleeve at 15,601 w/3.813" BX profile D. HES or equivalent XN no-go nipple at 15,612 w/3.725 No-Go E. Weatherford Temp/Pressure gauge at 15,657'w/3.890" I.D. F. Baker 7-5/8" Premier packer at 15,909'w/3.840" I.D. G. HES or equivalent RN nipple at 15,929'with/3.375" No-Go 14. If unable to reach RN nipple at 15929 call Anchorage with depth attained. 15. POH with wireline equipment and shut in well. 16. RU SLB CT BOP. a. Add single ram BOP for 2nd barrier. • • 17. RU SLB CT unit(and N2 unit/diesel supply tank or truck,Great Northern test equipment to well as required)w/enough lubricator to swallow Baker KB Packer assemblies OAL (25'+-). a. Ensure we have enough lubricator to swallow upper assembly for when we strip back on. 18. MU Baker assembly as follows w/Baker representative present: 2-3/8"CT connector to 2-7/8" EU 8rd box by 2-7/8" ST-L pin/Baker provided 20'+-bull-plugged pup/float double float collar (the whole float collar assembly acts as the blow out plug and drops into the perforated put.) Pup minimum length determined by placing TWENTY FIVE OR MORE Y:" holes in top end of pup to provide greater X/S flow area than 3.202i2 XS area of ID of coil string.Check that pup OAL is long enough to swallow OAL of double float collar assembly completely below perforated area of pup after shear out occurs. a. BHA will include a 1.71" R profile nipple above the float collar assembly to facilitate plug installation and a pressure barrier if the string should be pulled in the future. b. The double float collar assembly is a primary barrier from wellbore after we have RIH to the desired depth,secured pipe and have open ended coil above the BOPs. c. Pull test and pressure test CT connectors and the blow out float assembly as required. 19. MU assembly to CT and PU into lubricator and hook up lubricator to well as per SLB engineer. a. Perform backside pressure test of riser. Test will be limited to 500 psi. Verify pressure limitations prescribed here with SLB coil supervisor and Baker representative prior to this test. 20. RIH fluid packing coil w/diesel while RIH w/required amount of SLB coil string(approximately 13783'of coil)to place bottom of perforated and bull plugged pup at 15829'and top of Baker Packer assembly at 2000' MD when top of CT is attached to Baker packer assembly in next step. See item 6 above for restrictions in tubing less than 3.958"nominal I.D. of 4-1/2"completion string. a. The double valve float system consists of two one way valves allowing flow down the coil only. 21. When 13873'of 2-3/8" coil is in hole close BOP pipe rams on coil string. 22. Check for and relieve any pressure on CT tubing. Verify that herculite or acceptable substitute is bermed utilizing sills or acceptable substitute to capture 110%of the maximum volume of return fluid that may be released from coil or lubricator during cutting process. 23. Bleed down any lubricator pressure as required. a. Once the BOPs are closed,an inflow test through open inner and out reel valve to the return tank can be performed to ensure zero pressure and no-flow.This will verify the integrity of the blaw&v plu . Perform 30 Minute no flow test. � c b b. If no flow,strip off the well witi'thes C z Injector Heade 3 24. Prepare for and install hot tap to the CT to facilitate controlled bleed down of coil. a. Place bucket under coil going to back deck prior to tool make up. b. Cut coil tubing. 25. Install swivel to allow CT stub above BOPs to make up to the Packer assembly suspended in the lubricator assembly. • • 26. MU Baker KB Packer assembly consisting of 2-3/8" CT connector, Baker 45 KB Packer,CTLRT running tool and Hi-Load Hydraulic disconnect to coil. PU packer assembly into lubricator and MU to stub. 27. Re-install lubricator. S a. Place a quick test on sub to re-check connection. t x�,c A 28. RIH to place bull plugged shoe at at 15829'MD and top of Baker KB packer top at 2000' MD. Lit 29. Fluid pack while RIH. 7 o f 30. Drop 5/8" ball w/ball size checked and verified by Co. Man prior to dropping ball. 31. When ball on seat pressure up to set KB Packer pinned w/2 pins to 1000 psi per Baker representative. 32. Slack off to check packer set and put CTLRT into compression per Baker representative. It is critical that CTLRT is in compression. Pressure up to 1500 psi w/diesel to activate CTLRT and blowout float assembly on bottom of string. A 3/" ball may be dropped to the CTLRT for emergency release. A Hi-Load Disconnect, requiring a 7/8"ball, is also in the string above the CTLRT as a backup emergency release in the CTLRT. 33. PU and check weight. If not free follow retry pressure procedure. A%" ball may be dropped to the CTLRT for emergency release. A Hi-Load Disconnect, requiring a 7/8" ball,is also in the string above the CTLRT as a backup emergency release in the CTLRT. 34. If free pickup 10'and pump N2 down coil until all diesel from 2000'MD to surface and process flow through Great Northern Testers equipment. 35. Immediately begin well test per Great Northern Tester's rep when N2 has dissipated and fluid is back to surface. 36. POH w/CT and into lubricator w/CTLRT assembly. 37. Shut well in as required w/swab and master valve on tree. 38. Perform all bleedoffs as required w/ability to control bleedoff release volumes as in step 22. 39. RD CT unit. 40. Begin well test. - (-- ✓9P -}���, P4' e 41. When well testing is concluded rig up Pollard Wireline to run BPV or SSSV if requirea • • • v z t i 1 3 K i` "d/. y f a '1 :y f_ E ; = ,x u 0 < "" V N t • if = -; n j J v+ R f a o z :o :G. x- c n G�3 x ` J Z p8 U sZ �g m u E V � . ; R' � ; i agti o Z $ `! „t s m • o v' ; cgm V. a a b O 3 �4 !\. ✓� 4 1 a = 11. g 1 \� �� a m x a A s / a o I g 3 n u o `%,,ti P• \ SL, 0 0 0 3 0. 1 y ; a N < n g / : G G O rG O V to ad - 9 O B 3 7 x o= *3 tv o a .w, e j '� j * o v i .Fa` L., 3 a iia / a � /4 ,.e S _a. O 4 - R $ o n (D Q e' • o 3 C7 Z $ i $ iO o ° c N co a Z t 4 a ofD " c F 3 0 = ' -' qq : 1—1': C 1)7 I $ 3 ° U) - = 0 r r 0. s ci 4 0 a y t, 5 8 :� N in Milli C,� C F. r x st -� n � 'Woli 3 " Aa Y u ,r f r 5 g a m EL z $ e n • r a r Ci q ^ o p C, ,.,.` o V -J .....t • • Tree Cap 4-1/16 API 5000 Flange Btm x 9.500-4 ACME Male Thread Otis Top with 4-1/2 API UPTB Internal Lift Thread API Temp Class K Material Class DD PN 257704 Swab Valve 4-1/16 API 5000 HWO WKM Saf-T-Seal Manual Gate Valve.API Temp Class K, Material Class EE-0.5 SSV Wing:4-1/16 API 5000 WKM PN 2087141-01 Model M Gate Valve with MA20 Pneumatic Actuator, API Temp Class U. HWO Wing Valve: 4-1/16 API 5000 WKM Material Class BB,Class II(Sandy Svc) Saf-T-Seal Manual Gate Valve API Temp Class K. Material Class EE-0.5 PN 2087161-01 t- ow 9 Tee:4-1/16 API 5000 Run and Wing " API Temp Class K, Material Class DD-NL ` PN 2032424-01-08 Upper Master Valve:4-1/16 API 5000 WKM - Saf-T-Seal with Gatemaster Hydraulic Actuator. API Temp Class K, Material Class EE-NL PN 2087163-02 A *dr ,t t -46 Master Valve: 4-1/16 API 5000 HWO WKM Saf-T-Seal Manual Gate Valve. API Temp Class K.Material Class EE-0 5 PN 2087141-01 +i ' • T .t. . ' 1411 0 a r � • • th BLUE CREST ENERGY CAMERON Hanson 1AL1 Tree Cap:4-1/16 API 5000 Flange Btm x 9.500-4 ACME Male Thread Otis Top with 4-1/2 API UPTB Internal Lift Thread API Temp. Class K, Material Class DD PN 257704 Swab Valve:4-1/16 API 5000 HWO WKM Saf-T-Seal Manual Gate Valve.API Temp Class K, Material Class EE-0.5 PN 2087141-01 HWO Wing Valve: :4-1/16 API 5000 WKM Saf-T-Seal. Manual Gate Valve.API Temp Class K, Material Class EE-0.5 PN 2087161-01 -Tee:4-1/16 API 5000 Run and Wing i �� i „ ._�� API Temp Class K, Material Class DD-NL ill N��PI � PN 2032424-01-08 10 , (-- SSV Wing:4-1/16 API 5000 WKM Model M Gate Valve with MA20 Pneumatic Actuator.API Temp Class U,Material Class BB,Class II (Sandy Svc)—Valve shown 180 deg.from actual position.Actuator is toward back of well. Upper Master Valve:4-1/16 API 5000 WKM Saf-T-Seal with Gatemaster Hydraulic Actuator. API Temp Class K, Material Class EE-NL PN 2087163-02 Master Valve: 4-1/16 API 5000 HWO WKM Saf-T-Seal Manual Gate Valve.API Temp Class K, Material Class EE-0 5 PN 2087141-01 S • ---- 4...1 . 7._,..44 .''-ir -if-. ..., ' ,4'4 It''. . •.,,,,,,....* a', .. , • ' .;•'''4,244..„.4.:2,,,...)4 ,141•4444:.-i'.. '44. . •,, ' ) tf4 , , ....".... 4-k. ::,' .,. t''• -t.'W••'... 1:'4.' . • ,..• 'I' +%••.',. ' ' --.• ., . 4Ir 44 .. ;••:: '-. ..:....'4/.1' ,. • i.' .ie ;.•' •...: - • i ••••• '1' • • • V 416 * - , •.. • , • '4&7••• ..4.. ,77 - ... . , .. ,, '- . .• ., ..... , ,• . " *' . , .1 • ... - ..... , , • ..., - . - • 1.- ' ...._ . , -, '40 . • - . ... if„ctwre**.*--.-*•„-.*4ftroogili4A -,-mamc=r=-- „..., ,.... .. „... ...._ ...,, _.........._ _ - . 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O r. / ill 4. • - mi n r- A A.W IV - o N i�3 CD F, m I I I I x p se 2, \ D NNmm N LI k 30 4 1) n'4ms nom; o 9 r " o m o m y t$ ' at a ic0 3e / 3 3 CI " w P %4,1 lc in To' < �`` .'1` lk X L. ( I . .10111. W er C I -7n I 1 `'_ j O n Octu CD T r sr .,,1-:' v d —I ; ' CD CO 4 gigili CA 1 l 9 I �, .1 r a r Il� II =. aCO Ct) /I ,1 1,,.� -0 r- 7 'p v r = T (� v , ,p c c c -D 'V 1,1 E O A m m m m m �r n I, rt I.1 A y 4t 3 - o < N N N M� m 4 1rq 1' ,� Cr X - t0 — r � W n a I n© . oW �X 1 1c Co z '71 e-t = _r no %, �1 1. ,� - lips,, N . 44. 13 z g a © C C t �i 'f. p 0- 2.�� r :� 3 o m C f1 co I J F i • • ..... ...' co 3 —4 < cv Z = Cr rD 0- --N CD M t—f- 1\\ kr. co NJ C u j oo Do z. X- CM CD 4t. Z 1 n o 0 0 = 5 A- a V) OD m --, a) a = 0 i—A C > 1--% cro r— nn -f, r—t• 0 Pr— * 77 CU e't CD 0 CI —. v.* -.< r—t• —. 0 Cfq • • AOGCC Questions Regarding Hansen 1 Velocity String 1. Need a current well schematic. file provided. 2. Current wellhead diagram from vendor.Cameron tree schematic file and picture provided 3. BOPE sketch for CTU . File provided. 4. Can you provide a drawing of the blowout sub/ported pup with checks. Files provided. 5. What is CTLRT ??( my guess is Coil tubing liner running tool?)Coil Tubing Liner Running Tool. 6. Need better schematic of how piping will be arranged and if there will be a functioning SVS on surface. Talked to Pollard about a Porta Power with a line to SSV. On the GNT drawing what are the blue dots and where is the wellhead exactly? Blue Dots are future wells. Drawing revised. 7. In general, it sounds like you are installing a semi-permanent CT velocity string(fluid will flow up the 2 3/8" coil)from 15800 ft to 2000ft. at that point the coil will displace the fluid down to 2000 ft with N2. As I read it the CT will stay in the wellbore while you flowtest the well. No. The CTLRT and above will be pulled as soon as N2 blowdown takes place and injector head will be removed from well. Assume you will be lift with N2 as you need it also (after bleeding off to zero)using the Coil lift point at 2000 ft md. No plan to do this. 8. i don't understand your"Notes" page . Wouldn't the produced fluid flow between the 2 3/8" CT and tubing annulus above 2000ft to the surface. Schematic provided. Flow from 15800 to 2000'will be only up the 2-3/8"velocity string. Above 2000' it will be up the 4-1/2"tubing to surface. (from 15800'to 2000 ft the fluid would flow inside CT). What does SLB Coil using a 2" 1502 mean? Schlumberger will bleed off their lubricator after POOH w/CTLRT and closing tree master/swab valves as necessary with appropriate lines and equipment to bleed down any pressure and capture all liquids from the lubricator. wouldn't production come off the blinded wing valve with at 1502? Yes all flow, test, and produced volumes will be produced through the 4-1/16"wing valve to the test equipment and then to tank. If you are thinking of flowing up the CT with produced fluids then we need to discuss this.. normally that is taboo. There is no plan to flow into reel on CT unit. Flow will be taken off via wing valve and then through test equipment. Any oil that is produced will need to be accounted for and either reinjected or sold to Tesoro. Will need an approved method for custody transfer if you are selling the test oil to Tesoro. Produced fluids will be reinjected into well except for a one barrel sample which will be used for assay purposes. No oil will be sold. • • Schwartz, Guy L (DOA) v1 From: Randy Frazier <rfrazier@bluecrestenergy.com> Sent: Wednesday, September 30, 2015 1:36 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) "' - IA 2o l- (S7 Subject: RE: MASP for Hansen 1AL1 flowback (15D-267•=079)-- Attachments: Baker45KB Pump Out Sub DRWSET.PDF; Baker Dual Flapper Valve.pdf Guy, We are using a MASP of 3100psi assuming that gas has fully displaced the oil out of the wellbore. I doubt we will see this but it's better to plan for it. The second highest pumping pressure will be when we shear the plug out. It will require around 2700psi surface pressure. Initial pumping of diesel Reservoir Pressure 3100 Hydrostatic of Gas 28.6 neglible Assumed initial MASP 3100 psi Our pump pressure once we get diesel in the hole from 2,000'to TD will be: Final Pumping N2 with diesel column below Reservoir Pressure 3100 Hydrostatic Head of diesel 1,703 1,397 MASP psi Realistically we will have some gas cap from swapping with a long column of oil which will keep our pump pressure down to the 1400 to 1S00psi expected when the top 2000' are displaced to nitrogen. The well does not have a hydraulic control panel on it now. We will connect a portable panel during all workover operations. The panel will be operated remotely next to the operator during each phase of the workover. Attached are the pump out sub drawing and the Baker Flapper Valve Assembly. I included the latter in case you are interested. Let me know if you have any other questions. Regards, Randy Frazier Drilling Manager BlueCrest Energy (o) 907-754-9559 1 • • (c) 907-250-4420 From: Schwartz, Guy L(DOA) [niailto:guy.schwartzOalaska.dov] Sent: Wednesday, September 30, 2015 12:02 PM To: Randy Frazier(rfrazierCa)bluecrestenergy.com) Cc: Davies, Stephen F(DOA) Subject: MASP for Hansen 1AL1 flowback(PTD 207-079) Randy, I missed requesting a MASP(max anticipated surface pressure ) value for the wellwork. I assume it will be during the N2 pumping but I need an estimated reservoir pressure and a max surface pumping pressure during the job. It looks like you will have the SVS panels operational but it must be tied into a ESD system during the flowback unless your testers have their own system. Do you have a complete drawing of the blowout pup joint showing all components.?? Can be hand drawn.... Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 • • AOGCC Questions Regarding Hansen 1 Velocity String 1. Need a current well schematic. File provided. 2. Current wellhead diagram from vendor. Cameron tree schematic file and picture provided. 3. BOPE sketch for CTU . File provided. 4. Can you provide a drawing of the blowout sub/ported pup with checks. Files provided. 5. What is CTLRT ??( my guess is Coil tubing liner running tool?)Coil Tubing Liner Running Tool. 6. Need better schematic of how piping will be arranged and if there will be a functioning SVS on surface. Talked to Pollard about a Porta Power with a line to SSV. On the GNT drawing what are the blue dots and where is the wellhead exactly? Blue Dots are future wells. Drawing revised. 7. In general, it sounds like you are installing a semi-permanent CT velocity string(fluid will flow up the 2 3/8" coil)from 15800 ft to 2000ft. at that point the coil will displace the fluid down to 2000 ft with N2. As I read it the CT will stay in the wellbore while you flowtest the well. No. The CTLRT and above will be pulled as soon as N2 blowdown takes place and injector head will be removed from well. Assume you will be lift with N2 as you need it also (after bleeding off to zero) using the Coil lift point at 2000 ft md. No plan to do this. 8. I don't understand your "Notes" page . Wouldn't the produced fluid flow between the 2 3/8" CT and tubing annulus above 2000ft to the surface. Schematic provided. Flow from 15800 to 2000'will be only up the 2-3/8"velocity string. Above 2000' it will be up the 4-1/2"tubing to surface. (from 15800'to 2000 ft the fluid would flow inside CT). What does SLB Coil using a 2" 1502 mean? Schlumberger will bleed off their lubricator after POOH w/CTLRT and closing tree master/swab valves as necessary with appropriate lines and equipment to bleed down any pressure and capture all liquids from the lubricator. wouldn't production come off the blinded wing valve with at 1502? Yes all flow, test, and produced volumes will be produced through the 4-1/16"wing valve to the test equipment and then to tank. If you are thinking of flowing up the CT with produced fluids then we need to discuss this.. normally that is taboo. There is no plan to flow into reel on CT unit. Flow will be taken off via wing valve and then through test equipment. Any oil that is produced will need to be accounted for and either reinjected or sold to Tesoro. Will need an approved method for custody transfer if you are selling the test oil to Tesoro. Produced fluids will be reinjected into well except for a one barrel sample which will be used for assay purposes. No oil will be sold. • S Schwartz, Guy IL (DOA) From: Randy Frazier <rfrazier@bluecrestenergy.com> Sent: Monday, September 28, 2015 4:20 PM To: Schwartz, Guy L(DOA); Regg,James B (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Hansen#1AL1 Workover(PTD 201-157) Attachments: Hansen 1AL1 Sundry Request_pdf; AOGCC Questions Regarding Hansen 1 Velocity String.docx; Baker45KB Pump Out Sub DRWSET.PDF; Baker Dual Flapper Valve.pdf Guy, Here is the latest Sundry request. I think we covered most of your questions. I'm going to add an estimated gas volume (which will be small)I to the cover letter before I submit it in duplicate. I'm just waiting for an anticipated number from our reservoir engineer. Besides the Sundry Application I have added some other documents for your review—answers to your questions and some design detail on the Baker equipment. Please take a look and let me know if there is anything else you would like to see. Thanks, Randy Frazier Drilling Manager BlueCrest Energy (o) 907-754-9559 (c) 907-250-4420 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 22, 2015 4:04 PM To: Randy Frazier; Regg, James B (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Hansen #1AL1 Workover(PTD 201-157) Randy, You may just submit a hard copy (2 copies) as long as the questions and other documents are included. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation C orrirnisslcn IAC;GUL,l,State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793.1226 I of (Guy.schwgrta^aiaska.gov). 1 • • From: Randy Frazier [nailto:rfrazierhluecrestenergy.com] Sent: Tuesday, September 22, 2015 4:00 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Hansen #1AL1 Workover (PTD 201-157) Guy, Thanks for this. We will make these changes and submit a hard copy of the 403. We will keep the coil in the well until the well starts flowing then pull out. If we need extra N2 to kick the well off we will just pump it down the coil.The well will produce up the 2 3/8" coil to 2000' then will flow up the CT/tubing annulus while the CTU has coil in the well—then up the tubing when the coil is out of the hole. We absolutely are NOT thinking about flowing up the coil on the CTU. We plan on reinjecting all fluid produced from the well. We will make sure all the rest of your questions are answered with proper diagrams and comments. Would you like an electronic copy when we are done or should I just submit a hard copy? Thanks again for your help. Regards, Randy Frazier Drilling Manager BlueCrest Energy (o)907-754-9559 (c) 907-250-4420 From: Schwartz, Guy L (DOA) [mailto:guy.sc` .vartz@aialaska.gov] Sent: Tuesday, September 22, 2015 3:31 PM To: Randy Frazier; Regg, James B (DOA) Cc: Davies, Stephen F(DOA) Subject: RE: Hansen #1AL1 Workover (PTD 201-157) Randy, Here are my comments: 1. Need a current well schematic 2. Current wellhead diagram from vendor. 3. BOPE sketch for CTU . 4. Can you provide a drawing of the blowout sub/ported pup with checks 5. What is CTLRT ?? ( my guess is Coil tubing liner running tool?) 6. Need better schematic of how piping will be arranged and if there will be a functioning SVS on surface. On the GNT drawing what are the blue dots and where is the wellhead exactly? 7. In general, it sounds like you are installing a semi-permanent CT velocity string(fluid will flow up the 2 3/8" coil) from 15800 ft to 2000ft. at that point the coil will displace the fluid down to 2000 ft with N2. As I read it the CT will stay in the wellbore while you flowtest the well. Assume you will be lift with N2 as you need it also (after bleeding off to zero) using the Coil lift point at 2000 ft md. 8. I don't understand your "Notes" page . Wouldn't the produced fluid flow between the 2 3/8" CT and tubing annulus above 2000ft to the surface. (from 15800' to 2000 ft the fluid would flow inside CT). What does SLB Coil using a 2" 1502 mean? ... wouldn't production come off the blinded wing valve with at 1502? If you are thinking of flowing up the CT with produced fluids then we need to discuss this.. normally that is taboo. 2 S • 9. Any oil that is produced will need to be accounted for and either reinjected or sold to Tesoro. Will need an approved method for custody transfer if you are selling the test oil to Tesoro. Regards, Guy Schwartz AOGCC From: Randy Frazier [ _,ilto`rfra tenergy ] Sent: Tuesday, September 22, 2015 11:26 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: Hansen #1AL1 Workover vuy, I have not officially submitted it. I was waiting on your feedback. Thanks, Randy From: Schwartz, Guy L(DOA) [ wartztaalaska.gov] Sent: Tuesday, September 22, 2015 10:48 AM To: Randy Frazier; Regg, James B(DOA) Subject: RE: Hansen #1AL1 Workover Randy, You won't need to submit a separate 10-403 to flare but I would recommend you add some extra verbage in the 10-403 requesting to flare and your estimated total flare gas for the operation. You may temporarily flow test the well without a SSSV as long as the operation is manned during flowing periods. I am reading your submitted 10-403 sundry in detail and will have several questions for you. Have you already submitted a hardcopy? Guy Schwartz AOGCC 907-793-1226 From: Randy Frazier [ •crestenergy,com] Sent: Friday, September 18, 2015 11:58 AM To: Schwartz, Guy L (DOA); Regg,James B (DOA) Subject: Hansen #1AL1 Workover Guy and Jim, I have attached a 10-403 for the workover we are planning on Hansen#1AL1 in the Cosmopolitan Field. We are hoping to pull existing BPV's in the well, run a 2 3/8" coil velocity string, displace the top of the well to N2 and then put the well on production through portable well test equipment. I have attached a copy of our procedure so you can see our plans. We hope to flow 3 tubing volumes of oil out of the well so we can capture one barrel of formation oil. This sample is required for an assay by Tesoro. We anticipate running through the well test equipment no more than two days during 3 • • daylight hours.We will be flaring associated gas during this time period. Do I need a separate 10-403 for permission to flare? Also,there is some question if this well has a SSSV ball valve in the well. Our records indicate it is in the well. However, Pollard shows it not in the well. If no SSSV is in the well,can we get a variance to flow the well without a SSSV during the two days we are flowing through the test separator?The operation will be manned at all times while the well is in test and we will only produce the well during daylight hours. Do I need a separate 10-403 for this variance? Please let me know if I can answer any questions. Feel free to call me anytime. Regards, Randy Frazier Drilling Manager BlueCrest Energy (o)907-754-9559 (c)907-250-4420 4 Image f. ~ject Well History File CeJer 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. doL - L 5 7 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: ~ '6 '6 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V Y~S I NO Helen( Maria ,3 Date: ~ cJ-O Of;; /5/ If NO in stage 1, page(s) discrepancies were found: YES NO Organizing (done) o Two-sided III" 11111111111111 RESCAN ~olor Items: o Greyscale Items: o Poor Quality Originals: DIGITAL DATA ~skettes, No. I o Other, No/Type: o Other: NOTES: BY: Helen ~~~ Project Proofing BY: Helen~. Scanning Preparation o x 30 = d-.70 + BY: Helen(M~ria ) BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed II OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ~09S of various kinds:~ o Other:: , ¡ Date:6 d/) OS Isl W;J II Date: f) ¡¡() ()S 151 Y\1~ I I 7 = TOTAL PAGES d.. <6~ (Count doe< not inclu.de cover sheet) ... Date: b ao ð!7ls1 , I IV}) Date: 151 II! 11111111111 1111I 111111111111111111I I Date: 151 Quality Checked 111111111111" 1I1I1 gar - � • s Shartzer, Christine R (DOA) From: Colombie, Jody J (DOA) Sent: Wednesday, March 16, 2011 10:00 AM To: Shartzer, Christine R (DOA) Subject: FW: Project details RE: Cosmopolitan Unit Voluntarily Terminated Please print and file in well files. SI 5 .. EP MAR 1 6 2011 From: Havelock, Brian E (DNR) Sent: Wednesday, March 09, 2011 10:20 AM To: Eddy, Allen R (DNR); Peterson, Terry L (DNR); Lewis, Dianna L (DNR); Poydack, Holly M (DNR); Haines, Jennifer H (DNR); Parrish, April M (DNR); Greenan, Dawn H (DNR); Timmons, Saree (DNR); Slemons, Jonne D (DNR); Buzby, Bruce 3 (DNR); Easton, John R (DNR); Frazier, Jeanne M (DNR); Buck, Teri A (DNR); Krouskop, Donovan L (DNR); Taylor, Cammy 0 (DNR); Decker, Paul L (DNR); Dennis, Alan R (DNR); Colombie, Jody J (DOA); Seamount, Dan T (DOA); McMains, Stephen E (DOA) Subject: Project details RE: Cosmopolitan Unit Voluntarily Terminated FYI I meant to reply on this matter. Arco drilled the initial Hansen #1 well 10 years ago. Pioneer bought the unit and drilled the Hansen 1A and 1A-L. All 3 well bores are inside a single mother -bore. All surface operations, including the Hansen well were done from a single surface location (gravel pit), where the subsurface and surface is privately owned (the Starichkoff oil field is entirely offshore). The Cosmo (aka Hansen) well broke the record for the longest horizontal departure ever drilled in Cook Inlet. The project went through a Development phase review more recently, which was very time consuming and controversial due to the site's proximity to the Cook Inlet bluff, Stariski Creek, and neighborhoods. If the leases terminate, so goes the permit is my understanding. Too bad they could not find a buyer. Brian From: Eddy, Allen. R (DNR) Sent: Tue 3/8/2011 1:45 PM To: Peterson, Terry L (DNR); Lewis, Dianna L (DNR); Poydack, Holly M (DNR); Haines, Jennifer H (DNR); Parrish, April M (DNR); Greenan, Dawn H (DNR); Timmons, Saree (DNR); Slemons, Jonne D (DNR); Buzby, Bruce 3 (DNR); Havelock, Brian E (DNR); Easton, John R (DNR); Frazier, Jeanne M (DNR); Buck, Teri A (DNR); Krouskop, Donovan L (DNR); Taylor, Cammy 0 (DNR); Decker, Paul L (DNR); Dennis, Alan R (DNR); Colombie, Jody J (DOA); Seamount, Dan T (DOA); McMains, Stephen E (DOA) Cc: Eddy, Allen R (DNR) Subject: Cosmopolitan Unit Voluntarily Terminated On February 28, 2011 Commissioner Sullivan approved the voluntary termination of.the Cosmopolitan Unit. The Unit was terminated effective February 11, 2011. The following 5 Cook Inlet leases expired upon the termination of the Unit: ADL 384404, 387102, 389230, 389525, and 389526. AOGCC has already commented on the above mentioned leases, no further response is needed. Janne, ADL 384404 was issued effective 1 -1 -1995, with an original expiration of 12 -31 -2001. ADL 387102 was issued effective 2 -1 -1996, with an original expiration of 1 -31 -2003. ADL 389230 was issued effective 2 -1 -2000, with an original expiration of 1 -31 -2007. ADL 389525 was issued effective 5 -1 -2001, with an original expiration of 4 -30 -2008. ADL 389526 was issued effective 5 -1 -2001, with an original expiration of 4 -30 -2008. 1 • Allen R. Eddy Jr. Division of Oil and Gas 550 West 7th Avenue, Suite 800 Anchorage, AK 99501 Phone: 907- 375 -8259 Fax: 907 - 269 -8943 2 • • NOTE TO FILE Pioneer Natural Resources (PNR) Hansen #1AL1...207-079...309-131 CPAI /PNR Hansen #1A .. 03-004 PPCo Hansen #1 201-157 Request to Resume Annular Disposal PNR has submitted a sundry application requesting approval to resume annular disposal into the Hansen #1A (203-004). This document evaluates PNR's request and recommends approval. Disposal into the 9-5/8" x 13-3/8" was originally authorized (302-006) when Phillips originally drilling in 4Q 2001 - 1 Q 2002. That approval also authorized PPCo to dispose of up to 75,000 bbl of drilling waste and rain water/snow melt. Subsequent approvals (302-224) were given to exceed the EMW at the surface casing shoe as specified in the original approval and (303-004) increased the total disposal volume to 140,000 bbls. When PNR permitted the Hansen #1AL1, approval (307-213) was obtained that increased the total disposal volume to 170,000 bbls. The prior "notes to file," relating to sundry approvals 302-006, 302- 224, 303-004 and 307-213 are incorporated by reference for this discussion. To date, a total of 164,354 bbls of wastes have been disposed into the 9-5/8" x 13-3/8" annulus. Temperature logs were conducted by PPCo /CPAI during the early disposal operations as required by their sundry authorizations. The interpretation of the temperature logs was that the wastes were being accepted by formations below the 13-3/8" shoe. The most recent log was conducted March 18, 2003 and indicated a cooling occurring at about 6030' and (3583' tvd) which is ~ 850' and (240' tvd) deeper than the 13-3/8" shoe. No temperature log has thus far been required by PNR. So far as can be determined examining the batch injection reports submitted by PNR, it appears that annular disposal is being. conducted in accord with 20 AAC 25.080. PNR was considering further drilling at the Hansen drill site, however any new drilling has been delayed for the foreseeable future. Slightly less than 6000 bbls. of disposal volume remains available under approval (307-213) and the miscellaneous volumes of precipitation and any well work waste should be easily accommodated. PNR does not have any other option for local environmentally acceptable disposal alternatives. Based on this analysis, the following is recommended. 1. Approval for PNR's request to resume annular disposal into the 9-5/8" x 13-3/8" annulus of the Hansen #1 / Hansen #1A is recommended. 2. The prior approval to exceed the previously established 14.3 EMW limit at the surface casing shoe of Hansen #1 is affirmed. (302-224) • 3. The surface pressure while pumping may not exceed 1500 psi. (302-224) 4. The disposal rate shall not exceed 2.5 bpm. (307-213) 5. PNR shall monitor the surface pumping pressure at all times while disposal is occurring and cease disposal operations if the pressure information indicates that the waste is not being confined below the shoe. (307-213) 6. PNR shall maintain a log of their disposal operations noting the volumes and type of waste disposed, the weight of the slurry pumped and representative surface pressures while pumping different fluids (ie clear water or slurry). (307-213) 7. The maximum disposal volume remains at 170,000 bbls. (307-213) 8. PNR should obtain temperature surveys prior to and immediately after commencing annular pumping operations and submit interpreted results to the Commission within 2 weeks of completing the subsequent survey. 9. All other requirements of 20 AAC 25.080 apply. Cr'~"~~~ Tom Maunder, PE Sr. Petroleum Engineer April 16, 2009 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, (p'i Chair '. ryr¿ Tom Maunder, I:ff; P. I. Supervisor ">l~-Ð'0~ DATE: January 19, 2002 THRU: ~ ..--7 "'0""'" " ,,'" rt~,.,,·t2b, ,- ~ ,¡..', . FROM: Lou Grimaldi, Pe5~~uf1il~~~ctor SUBJECT: HanS$n#1. Crude Oil Custody Transfer issue Exploration CONFIDENTIAL I have been in contact with Jack Kralick (Phillip's Rep.) concerning the disposition of the crude oil that will be produced during the well tests at Phillip's exploratory well, Hansen #1. During an inspection at the Hansen well I looked over the tankage to be used to collect the crude. There are ten, four hundred barrel tanks connected to manifolds. These tanks are standard bulk tanks and although should do well to hold the crude and give an approximate volume, are not suitable for custody transfer measurement. This crude is to be collected and transferred to the Beaver Creek facility by tanker trucks. The Crude will then be metered through this facility's L.AC.T. unit. We presently do not witness meter provings or do L.ACT. inspections at this facility. I recommend the following; 1. The L.AC.T. unit at Beaver Creek should be proved during the first batch and a witness from the AG.G.C.C. should be present. 2. Representative samples from each batch sent through the meters should be collected, tested for quality (B. S. & W.) and retained for a time determined suitable by the A.G.G.e.c. This should also be witnessed. 3. Tickets should be generated and retained for each batch shipped through the meters. If the crude from Hansen is significantly different in gravity than the temperature compensator is ranged for adjustments may need to be made. The proving company should be prepared to make these changes and document all adjustments. I have spoken with John Spaulding and he will follow this while I am on the North Slope this coming week. I request I be copied on the progress in this situation. E'>~ct~\\ÍJ.\\ì \\~ ~~~vó~~ wtJ..S 0v'\D '-'Cc 'à ~ ~f2V¡ CONFIDENTIAL 020119-Meter Oil Hansen #1 LG.doc . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc Î 7 14) ÀJ~~)' DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 )PiÄ ¿ .,{ I ÓJ;- Å»û ¡ Permit to Drill 2011570 Well Name/No. HANSEN 1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-231-20010-00-00 MD 18630 ~ TVD 7418.V"" Completion Date 4/17/2003"'/ Completion Status P&A Current Status P&A UIC N ~._-- REQUIRED INFORMATION Mud log ~ "l tA.-.. Samples No Oirectional Survey N1r" \/ ~ DATA INFORMATION Types Electric or Other Logs Run: MDT, CMR, lWO, Triple Combo (GR, Res, RHOS, NPHI), PWD, MUD Well Log Information: (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Typ,& Med/Frmt Number Name !'"ÉÓ C 1~78 See Notes ~ C 49677 See Notes I i log Sonic - Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 16846 18516 Case 3/27/2002 CMR flog Log Formation Tester Temperature 5 2 Myl Slu 16844 18470 Case 3/27/2002 Processed CMR data and displays 354 14835 Case 6/10/2002 Ultra Sonic Casing and Cement Imager 703 18630 Open 4/16/2002 RWO- GRlMPRlNEUT/DEN 17035 18447 Case 6/10/2002 4850 6000 12/16/2003 Temperature Injection Survey 4850 6000 12/16/2003 Temperature Injection Survey 5 Myl .-/'ÉÓ C t..(Q756 See Notes 4- Log L___ Well Cores/Samples Information: Injection Profile 2 Slu Name Interval Start Stop Sent Received Sample Set Number Comments _C~ ADDITIONAL INFORMATION Well Cored? ~ Daily History Received? ?)rN ~/N Chips Received? - ¥ J bI - Formation Tops Analysis Y / N Received? ------ Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2011570 Well Name/No. HANSEN 1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-231-20010-00-00 MD 18630 TVD 7418 Completion Date 4/17/2003 Completion Status P&A Current Status P&A UIC N Compliance Reviewed By: JL~ Date: IYM; ~r ~. - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2002/1st 14769 100 2002 / 3rd 52255 100 2002 /4th 472 100 2003 / 2nd Hansen 1 A = 3299 Hansen 1 = 44083 Hansen 1 A =100 Total Ending Volume (bbls): 114878 400 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D 4a. Well Class: Stratigraphic D Service D Development D Exploratory 0 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 302-006 / 303-004 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/28/2003 Volume (bbls): Number of days disposal occurred o 14869 o 52355 o 572 o 47482 o 115278 Step Rate Test D I hereby certify that th~ing i: true and correct t~ .th: best of my knowledge. Signature: I ~ fY/~ Printed Name: ~tfH,^L MlIl'Z-ZD ".jfJ' Form 1 0-423 Rev. 9/2003 Date: Title: DJe.IL,L..J .J ê T£14M L.eiltbé:~ INSTRUCTIONS ON REVERSE SIDE Page 1 RECEIVED JAN 2 8 2004 6. Permit to Drill ANu'amS~~:Gi' & Gcu c~J.-è8tki~£'nn 7. Well Name:· LRansen #1 AncHorage 8. API Number: 9. Field: Disposal Beginning Dates: 10 1/13/2002 35 7/12/2002 1 10/1/2002 46 4/20/2003 50-231-20010-00 Exploratory Disposal Source Wells: Ending Dates: ~/ 3/20/2002 Hansen #1 9/30/2002 Hansen #1 1 0/1/2002 Hansen #1 6/28/2003 Hansen #1 A '-" Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 92 b'l zz / ð4- Phone Number: 2b3 -4'03 Submit in Duplicate Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 114878 400 0 115278 92 2498 100 0 2598, 7 7/5/2003 7/31/2003 Hansen #1 A 1809 100 0 1909 6 10/14/2003 10/22/2003 Hansen #1 A 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development D Exploratory 0 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 302-006/303-004 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 3rd 2003 / 4th YYYY /0# YYYY /0# Total Ending Volume (bbls): 600 o 119785 105 119185 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ?J rr¡~ Printed Name: ~ (.,i L I'll I'r z. Z 0 1-1 j,I.J , 6. Permit to Drill Number: 7. Well Name: 8. API Number: 201-157 Hansen #1 50-231-20010-00 9. Field: Exploratory Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~' -~/ Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. Date: () t/Z:z..¡ 04- Ð,(fLLltJ6 TEAM UJ1ì)E:]L Phone Number: Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 71" '3 -4/p03 Submit in Duplicate 57 I ~o Source Wells End Date Start Date New Total Previous Total Freeze Protect Volumes Total for Quarter Annular Disposal during the third quarter of 2003: h(l) h(2) h(3) V olume V olume Volume CD2-20, CD2-55 35-19 Hansen lA July 2003 July 2003 July 2003 ( 1 CD2-40, CD2-30, CD2-55 1B-102, 1B-101 CD2-18. CD2-55 Hansen Sept 2003 Sept 2003 Sept 2003 June 2003 June 2003 January 2002 July 2003 July 2003 Sept 2003 24037 7253 117876 4000 4659 115278 377 361 o 19660 2233 2598 o o o 00 00 00 19560 2133 2498 Name CD2-41 3S-17A \Vell 30011 36755 22617 o o o 389 o 377 29622 36755 22240 o o o 00 00 00 29522 36655 22140 - Hansen 1 CD2-38 IB-20 CD2-23 Volumes into Annuli,for which Disposal Total Source Wells CD2-12 CD2- CD2- CD2-51 CD2-08, CD2-36, 51 CD2-45, CD2-35 08, CD2-28 End Date May 2003 March 2003 February 2003 Start Date April 2003 February 2003 December 2002 Status of Annulus Open, Freeze Protected Open, Freeze Protected 31864 31253 371 380 Total h(3) Volume o o Total h(2) Volume 00 00 Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume Total h(l) Volume 31393 30773 Well Name CD2-46 CD2-22 Open, Freeze Protected 32000 375 o 00 31525 CD2-48 { RECEIVED OCT 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage of2 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 10/1/20038:56 AM > > Chris Brown > > Chris Brown/Jason Charton > Exploration Field Environmental Coordinators > NSK 61 (Kuparuk) > Slope #: (907)659-7217 > Fax: (907)659-7314 > Cell: (907)240-5717 > Pager: 659-7000 #790 > Thank you for your consideration in this matter. > Since the annulus is still available for injection, we would like approval > to run this solid material through the MI grind and inject unit for annular > injection. This material was all generated during the drilling of the > exploratory well. > > While the rig was operational, it was surrounded by a large secondary > containment built with timbers and herculite. After the rig was moved, > approximately 18 bbls of drilling related waste from around the pits, rig > engines, and sub was removed from the containment using a vac unit. The > waste consists of drilling mud, rig dirt, rust, residues from rig wash > down, and other drilling-related oil residues that were contained > underneath the rig. > > Tom, > > I know you have worked with Mike Winfree on certain issues associated with > the Hansen well so I am sending another request your way for consideration. > Currently, ConocoPhillips is in the process of demobbing from the Hansen > well site. The drilling rig has been moved offsite and the well test > equipment and tanks are being decommissioned. > NSK Expl Env wrote: Chris and Jason, 25.080 (h) (1) thru (3) defines "drilling waste" as relates to annular disposal. From your description of the material and the source being the activities performed by the rig in drilling the well, it qualifies for disposal via your processing system and the annulus. Please call with any questions. Tom Maunder, PE AOGCC ems -Cf) \ Subj.e,::t: Re: Annular Disposal at Hansen Wel Dfite: Wed, 01 Oct 200308:56:29 -0800 Ffòm: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Expl Env <n1662@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> d-.O \ \ s, Re: Annular Disposal at Hansen Well ) ') ~. of2 9/1 0/2003 0:45 AM Grid N Please use all of the following coordinates in your planning and reports and attach a copy of this email and the attached document 2144659.501 When describing the Hansen #1 and Hansen #lA surveys, use the Grid Coordinates so that we may stay consistent where the Hansen wells really are in space. This will stay consistent with modern surveying tools as well all parties need in understanding also allow us to Due to this descrepency, converting the our modern system of measurement results in Grid N/E and Lat/Long coordinates to legal township/range descrition to in errors to the surface location Because this monument was placed so long ago, there is some error in its location when compared to the protracted or theorectical section lines Please the the attached document explaining the descrepency 2148' FSL, 1527 FEL Section 2, Township 4 South, Range 15 West, Alaska as survey from the section line monument placed by the BLM in SM, 1918 The To AII- legal description of the Hansen surface location is Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL Scott.D.Reynolds@ConocoPhillips.com I Sharon- forgot to send this to you when I sent it to everyone else To: cc: Subject Hansen Surface Location Coordinates Sharon Allsup-Drake/PPCO@Phillips 05/09/2003 01:59 PM Scott D Reynolds Thanks, Sharon wo r k : ( 907 ) 2 63 - 4 612 fax: ( 9 0 7 ) 2 6 5 - 62 24 office ATO-1530 sallsup@ppco.com Forwarded by Sharon Allsup-Drake/PPCO on 09/10/2003 09:27 AM Bob here is the letter you requested From To SubJect Date Hansen Surface Location Coordinates Wed, 10 Sep 2003 09:37:44 -0800 " Sharon Allsup-Drake" <Sharon.K.Allsup- Drake@conocophillips.com> bo b _ fleckenstein@admin.state.ak.us Hansen Surface Location Coordinates ) JOij'5~) - c!)~of/D 20f2 ~ Hansen Surface :Location Error. doc Name: Type: ~,~~?~~~~:..~.~.~~,?~ Hansen Surface Location Error.doc WINWORD File (application/msword) 9/1 0/2003 0:45 AM See attached file Hansen Surface Location Error.doc Regards, Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL Scott.D.Reynolds@ConocoPhillips.com Hansen Surface Location Coordinates ') ') Grid E: 168820.636 Latitude: 59 deg 51' 30.098 Longitude 151 deg 48' 05.720 2148 FSL 1527 FEL. Section 2. Township 4 South. Range 15 West. SM r--- Mailing Address: P.G. Box 468 Shipping Address: 38240 Kenai Spur HighW2Y Soldotna., AK 99669-0468 THE REASON FOR THESE DIFFERENCES COUlD BE ATI'RIBUTED TO THE FACT THE BLM RECTANGULAR SURVEY THAT MONUMENTED THE SECTION CORNERS IN TillS PARTICULAR AREA WAS PERFORMED IN 1918 AND THE BLM DID NOT HAVE THE MEANS TO DETERMINE THIER PRECISE GEOGRAPHICAL LOCATION IN THE FIElD. PLEASE N01E THE FOu..OWING DIFFERENCES IN TH E OFFSETS: HANSEN NO.1 FEL 1527 Fr. AcruAL SECTION LINE 1458 FT. PROTRACTED SECTION LINE DEiTA 69 Fr. FSL 2148 Fr. ACI1JAL SECTION LINE 2009 FT. PROTRACTED SECTION LINE DELTA 139 FT. ,.---.. PROM: MIKE B. WINFREE CONOCO PHILUPS ALASKA SCOITMcLANE ~--1+-H~ PHONE: 9072834218 EXT 206 FAX: 907 283 3265 EMAIL: msmclaoc@mclanc:cg.com. SUBJEcr: HANSEN NO.1 SURFACE LOCATION DATE: 12/11/2002 I HAVE REVIEWED THE OFFSETS TO SECTION LINES FROM THE WElL SURFACE LOCATION REPORTEDON THE ASBUILT SURVEY PREPARED BY OUR FIRM ON AUG. 7, 2001 AND FOUND THESE TO BE CORRECT BASED ON THE ACTUAL LOCATION OF THE MONUMENTED SECTION CORNERS. THESE VALVES HOWEVER DO NOT EQUAL OFFSET VALUES TO THE PROTRACTED OR THEORETICAL SECTION LINES. .~ TO: ~Con5uLting c;"roup ~Te5ting ) PROJECT MEMORANDUM ) CD2-50 1D-11 1C-18 31530 32102 32251 100 100 100 o o o 370 235 373 32000 32437 32724 Open, Freeze Protected Open, Freeze Protected Open, Freeze Protected July 2002 May 2002 June 2002 5ept2002 June 2002 July 2002 CD2-19, 23 CD2-41 1D-103 1 C-1 04 CD2-38 into Annulifor which Disposal Authorization Expired during the second quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 372 CD2-32 Well Name CD2-17 31337 Total h(l) Volume 17709 100 Total h(2) Volume 100 o Total h(3) Volume o 379 31816 18181 Open, Freeze Protected Status of Annulus Open, Freeze Protected June 2002 May 2002 July 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-41, CD2- ) Total Volumes Start Date End Date Source Wells CD2-19 CD2-41 3S-17 A 1C-19 3S-08B 31325 31610 30860 3900 4559 100 100 100 100 100 o o o o o 31425 31710 30960 4000 4659 o 290 377 377 361 o o o o 5020 31425 32000 31337 4377 5020 May 2003 May 2003 May 2003 June 2003 June 2003 Hansen 1 47382 100 o 47482 o 67796 115278 3S-16 31006 100 o 31106 357 o 31463 ) ,I CD2-46 31393 100 o 31493 371 o 31864 Puviaq #1 5063 100 o 5163 o 4731 9894 lC-22 21553 100 o 21653 o 27044 48697 March 2003 March 2003 March 2003 April 2003 April 2003 January 2002 June 2003 June 2003 June 2003 June 2003 June 2003 CD2-20 35-19 1C-184, 1C-170, 1C-172 35-24,35-03,35-19 CD2-58, CD2-52 June 2003 Hansen, Hansen 1A May 2003 April 2003 May 2003 April 2003 May 2003 35-23,35-17,35-06,35-16 CD2- 51 CD2-12 Puviaq 1C-190, 1C-174,lC-178, 1 C-19 3S-10 Annular Disposal during the second quarter of 2003: h(3) Total for V olume Quarter S-1- Well Name 9972 h(l) Volume f)O 100 h(2) Volume -\ o 10072 Freeze Protect Volumes 388 21204 Previous Total 31664 New Total Start Date End Date 35-21 Source Wells 35-08, 35-23 Regards. Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL Scott. D. Reynolds@ConocoPhillips.Gom TOTAL P.02 Ii) Hansen Surface Location Ërror.d( 21481 FSL, Grid N: 2144659.501 Grid E: 168820.636 Latitude: 59 deg 51' 30.098" Longitude: 151 deg 48105.720" 15271 FEL, Section 2, Township 4 South, Range 15 West, 8M Please lISè all of the following coordinates in your planning and reports and attach a copy of this em ail and the attached document. When describing the Hansen #1 and Hansen #1A surveys, all parties need to use the Grid Coordinates so that we may stay consistent in understanding where the Hansen wells really are in space. This will also aUow us to stay consistent with modern surveying tools as well. Due to this descrepency, converting the legal township/range descritíon to our modern system of measurement results in errors to the surface location in Grid N/E and LatlLong coordinates. Because this monumént was placed so long ago, there is SOme error in its location when compared to the protracted or theorectical section lines. Please the the attached document explaining the descrepency. 21481 FSL, 15271 FEL, Section 2, Township 4 South, Range 15 West, SM. Alaska as survey from the section line monument placed by the BLM in 1918 The legal description of the Hansen surface location is: To AII- cc: Subject: Hansen Surface Location Coordinates David C. Shafer/PPCO@Phillips, Deirdre L SchwartzlPPCO@Phíllíps, winton_aubert@admÎn.state.ak.us, Paul Mazzolini/PPCO@Phillips, nrose1 @slb.com :30 PM MRY-30-2003 10:23 PHILLIPS RK ) NC 907 265 6224 P.02 Date of Test: Hours Tested: Production data: 230 bbls oil, 46 MSCF, 0 bbls water, 200 SCF/STB GOR Flowing Tubing Pressure: 50 PSI Casing Pressure: 3,500 PSI Calculated 24 hour rate for: 115 BOPD, 23 MSCFD, 0 BWPD Oil Gravity (corrected): 27 degrees API from bottomhole sample after test March 3 48 hours 5.2002 #3 Date of Test: February Hours Tested: 14 hours Production data: 245 bbls oil, 28 MSCF, 0 bbls water, 115 SCF/STB GaR Flowing Tubing Pressure: 65 PSI Casing Pressure: 3,400 PSI Calculated 24 hour rate for: 420 BOPD, 48 MSCFD, 0 BWPD Oil Gravity (corrected): Not measured due to contamination with power fluid Tyonek Test: 16965' - 17465' MD #2 Date of Test: Hours Tested: Production data: 218 bbls oil, 43 MSCF, 0 bbls water, 197 SCF/STB GOR Flowing Tubing Pressure: 75 PSI Casing Pressure: 3,100 PSI average Calculated 24 hour rate for: 374 BOPD, 74 MSCFD, 0 BWPD Oil Gravity (corrected): Not measured due to contamination with power fluid 8,2002 January 26, 2002 14 hours #1 Date of Test: Hours Tested: Production data: 420 bbls oil, no gas data due to N2 lift water, GaR not measured Flowing Tubing Pressure: 70 PSI average Casing Pressure: 625 PSI average Calculated 24 hour rate for: 576 BOPD, no gas rate, 0 BWPD Oil Gravity (corrected): 25 degrees API (jet pump ift) January 22-23, 2002 17.5 hours (initial perfs and N2 and separator bypass, 0 bbls Hemlock Tests: 17555'- 17915' MD ift) Hansen # 1 ) ) Alaska Oil & Gas Cons. Commission Anchorage SR/skad MAY 2 2 RECEIVED Z003 CPAI Drilling/Wells Exploration Dri ng Engineer S. Reynolds f ConocoPhillips Alaska, Inc. is sending the enclosed supplement to the Well Completion Report for the P&A operations on the Hansen #1 well. It includes the daily operations summary for the entire drilling operations on Hansen #1. you have any questions regarding this matter, please contact me at 265-6253 Dear Subject: Mr. Davies Supplement to Well Completion Report for Hansen #1 (201-157/302-319) Steve Davies State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 May 21 2003 ConocóP'hiiii pS P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6253 ) J Scott Reynolds Exploration Drilling Engineer Drilling & Wells ORIGINAL ~\as~a 0\\ &. Gas Cons. commission ~"c."otaUe W\~'{ 1 4: 1\)\)3 RE.CE.\\IE.O PM/SR/skad CPAI Drilling/Wells P. Mazzohnl Exploration Drilling Team Leader Sincerely, If you have any questions regarding Scott Reynolds at 265-6253. this matter, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the P&A operations on the Hansen #1 well. Attachments include the daily operations summary, an as-built, a directional survey and test results. please contact me at 263-4603 or Dear Subject: Commissioner: Well Completion Report for Hansen #1 (201-157/302-319) Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 May 14.2003 ConocóP'hillips ) ') ,t P. o. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 Paul Ma~zolini Exploration Drilling Team Leader Drilling & Wells CONTINUED. O. N REVE1S~DÀ L ('''') '-) I G J L, I ~ '\ ~ Form 0-407 Revised 2/2003 Gf Submit in duplicate RBDa~~ q~ press. 27. Brief description of Submit core chips; " ~AY 3 0 2DD3 CORE DATA Ithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, f none, state "none". \\. LJ Q..\ \ <>. 'oG.~ ().£j (il::.c..~m\r-..~¡ Ç\ I ,I,' rfn. ~f\" ~(ct\\OC c · .W ~\().,"'" t:}¡:- 't}1 " I;; NONE if necessary). ¡1~.~1- .:. ,-'-I ; .. '''\: 1.i,Ei~Q2 ; ..__~~ '=:3:_.." ~ Flow Tubing psi Production for Test Period --> Calculated 24-Hour Rate -> 26. Date First N/A Date of Test Casing Pressure Production Hours Tested OIL-BBL Method of Operation GAS-MCF PRODUCTION TEST (Flowing, gas lift, etc.) Plugged & Abandoned OIL-BBL GAS-MCF WATER-BBL W A TER-BBL OIL GRAVITY CHOKE SIZE IGAS-OIL RATIO API (corr) Bridge plug set @ 16880' MD to isolate all perfs plugged off: 17915' - 17555' 7465' 7098' - 6958', 6924' - 6742' TVD existing perforations 6965' MD ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 25. SIZE N/A TUBING RECORD DEPTH SET (MD) N/A PACKER SET (MD) 17502' CASING SIZE 30" 20" 13.375" 9.625" 7" WT. PER FT. 0.5" wall 0.5"wall 72# 53.5/47# 26" GRADE 5L-B 5LX-56 L-80 L-80 L-80 TOP Surface 30' 30' 30' 30' BOTTOM 93' 696' 5175' 6823' 8622' 24. 24" 17.5" 12.25" 8.5" Driven 488 sx Class G, 315 sx Class G 386 sx 12.5 ppg Class G, 504 sx 15.8 ppg Class G, 96 sx G Neat 16 sx Class G, 474 sx 15.8 ppg Class G 72 sx LiteCrete HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22. RHOB, NPHI), CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD 21 Logs Run: MDT, CMR, LWD Triple Combo (GR, Res, PWD, Mud Log 4b. Location of Surface: TPI: Total Depth: 8. Directional (State Base Plane Coordinates): x- 168821 x- N/A x- 155037 Survey: Yes 0 NOU y- y- y- 9. Water Depth, N/A f Offshore: feet MSL 20. Thickness of Permafrost: N/A 2144659.5 N/A 2152497 Zone-4 Zone-4 Zone-4 Depth where SSSV set: None 7. Land Use Permit: N/A O. Total 8630' 175' (MD + TVD): 6880' MD 16712' TVD Depth (MD + TVD): MD / 7418' TVD 6. Property Designation: ADL 384403 ßpV (wu 899' FNL, 308'ßE'(, Sec. 33, T3S, R15W, SM Well At Top Productive Horizon: Total Depth: RKB 9. Plug Back Depth Exploration N/A 4a. Location of Surface: 100360, Well Anchorage, AK 99510-0360 (Governmental Section): 2148' FSL, 1527' FEL, Sec. 2, T4S, R15W, SM January 5, 2002 ~ 8. KB Elevation (ft): Date Comp., or Aband.: 6. Date Spudded: October 21 Date TO Reached: 7. 201-157/302-319 3. API Number: 50-231-20010-00 4. Well Name and Number: Hansen 5. Field/Pool(s): 3. Address: P. O. Box 2001 2. a. GINJ D Operator Name: ConocoPhillips Alaska, Inc. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND L~ I Well Status: Oil D Gas U Plugged D Abandoned ~ Suspended U WAG D 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development D L..~r-,IJ' u Completions _ Other Service D Stratigraphic Test 2. Permit to Drill Number: WINJ D WDSPL D No. of 5. Susp., April 11 /)1> ..ttf," 2003 "'vn'or~.tory 0 D tem 29: List all test information. Form 10-407 Revised 2/2003 Or-. . ",' "....... fI If none state "None" tem 27: If no cores taken, indicate "none" Item 26: Method of Operation: Shut-in, Other (explain). Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in 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). Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection Item 22: Attached supplemental of the cementing tool. . tem records for this well should show the details of any multiple stage cementing and the location tern 20: True vertical thickness. tem tem 8: the Kelly Bushing elevation in feet abour spaces on this form and in any attachments. 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). mean low low water. Use same as reference for depth measurements given in other tern 4b: Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal 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. TPI (Top of Producing Interval). General: This form leases in Alaska. water is designed for submitting a complete and correct well completion report and log on all types of lands and Printed N~ .. ÞzM~~Z~li~~ _' . " Signature ¡-a.....J!.. I ~ rIA/yo"""""" Title: Phone NSTRUCTIONS 28. ) GEOLOGIC MARKERS NAME MD Tyonek 3530' Hemlock 17772' West Foreland 8552' 31 30. LIST OF ATTACHMENTS Summary of Daily Operations hereby certify that the foregoing is Exploration Drillinq Team Leader Directional Survey, As-Built, rue and correct to the best of my knowledge. TVD 2869' 7040' 7383' Test Results conducted, state "None". 1. January 22-23, 2002 - 175551 - 179151 MD 2. January 26, 2002 - 175551 - 179151 MD 3. February 18, 2002 - 175551 - 179151 MD 4. March 3-5, 2002 - 169651 - 174651 MD see attachment for more details on each test RECEIVED MAY 1 4 2003 Alaska Oil & Gas Cons. Commission Anchorage Contact: Scott Reynolds 265-6253 OSI'3/2.003 Date Prepared by Sharon Allsup-Drake attach detailed supporting data as necessary. 29. Include and briefly summarize test results. ') FORMATION TESTS List intervals tested, and If no tests were 9/6/2001 9/5/2001 9/4/2001 9/3/2001 9/2/2001 9/1/2001 8/31/2001 9:00 - 00:00 9:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 00:00 07:00 9:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 00:00 07:00 19:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 00:00 07:00 00:00 07:00 19:00 00:00 07:00 19:00 00:00 07:00 19:00 5.00 5.00 7.00 2.00 5.00 7.00 2.00 5.00 MOVE 7.00 MOVE 12.00 MOVE 5.00 MOVE 7.00 MOVE 12.00 MOVE 5.00 MOVE 7.00 MOVE 12.00 MOVE 5.00 7.00 2.00 5.00 MOVE 7.00 MOVE 2.00 MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOB MOBMIR MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMI R MOBMIR MOBMIR Printed: Shut down for night. Pick and set A-legs, bolster and A-leg tube. Install pump room sumps. Set pump room buildings. Set motor sheds. Offload mud cleaning equipment. 95% of all rig components on site. Check for fluids in the OBM leak detection tube. (Dry) Shut down for night. Shut down for night. Set SCR complex. Set mud pits 1, 2 and 3. Begin hooking up lines and installing hand rails. Poly-Urethane coat the mats and sumps in the pump room floor. Begin figer installation for 5 1/2" DP on the derrick board. Complete lay put of derrick board warm up shack. Shut down for night. Shut down for night. Set #1,2 and #3 pumps. Install suction lines to pit. Complete installation of hand rails and lights on the mud pits. Build berms and set accumulator building. Continue fabrication of figers for 5 1/2" DP on the derrick board. Begin derrick board warmup shack installation. Weld bracing for fuel berm. 18 Nabors personnel on location. Shut down for night. Shut down for night. Construct fuel berm. Continue work on derrick board fabrication. Install seals in pump room. Remove bad hammer unions in mud discharge lines. Set desander, desliter and degasser. Layout for shaker installation. Pull wires from SCR house through pump room and sub. Shut down for night. Shut down for night. Adjust roof panels over mud pumps. Continue berm construction around rig. Set water tank. Begin derrick inspection. Remove bridle line guides below bridle line sheaves. Gouge out substandard welds out of drillers and off drillers side pinning assembly. Set shakers in place and begin bolting together. Shut down for night. Shut down for the night. Set hopper house, set stairs on drlg side, work on berms and steps around rig, set work platform and BOP landings in sub, build fuel tank float monitor, weld on derrick bridal line softeners, break exhausts stacks down for welding extensions on. work on preparing mud pumps for new liners and valve seats, hook up mudlines, unload trucks with TESCO top drives, fuel all equipment on locations. Shut down for the night. Shut down for the night. Continued work on mud pump fluid ends, install fuel lines from bulk tanks to motors & boilers. Continue stringing electrical lines, cleaning plugs and installing plugs @ SCR house. Fill engines w/oil, repair pressure switch on cold start compressor. Seal roof over pump room, complete fuel gauge on tanks installation. shut down for the night. One welder and helper working through night on stack extensions. Cleaning and installing brushes on rotary table traction motor, continue work on exhaust stack extensions for 3512's, continue work on derrick board, continued assembling fluid ends on mud pumps, remove old drilling line from travelling blocks and prepare to string drilling line. two welders and helpers working through night on derrick board. 5/1/2003 3:20:42 PM 8/30/2001 00:00 - 07:00 07:00 - 19:00 7.00 MOVE 12.00 MOVE MOB MOB MOBMI R MOBMIR Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 9/11/2001 19:00 - 00:00 00:00 - 07:00 5.00 7.00 MOVE MOVE MOB MOB MOBMIR MOBMI R One welder and helper working nights. Night welder and helper. Printed: 5/1/2003 3:20:42 PM PJSM. 9 OF 10 electric traction motors shorted. Hooked up blower motor hoses to dry out motors and retest today. Install discharge piping for gun line to feed mud cleaner. Weld pad eyes to desander/desilter rooom for gas buster frame. Install flowline header pipe supports and install header. Fabricate mud cleaner work platform. Continue installation of chain link fence around pits. PJSM, 9 of 10 traction motors on drawworks, rotary table and mud pumps, shorted, hooked up blower motor hoses to dry out motors. Install discharge piping on gun line to feed mud cleaner. 9/10/2001 9/9/2001 9/8/2001 07:00 19:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 - 00:00 00:00 - 07:00 07:00 - 19:00 19:00 9:00 - 00:00 00:00 - 07:00 12.00 5.00 7.00 12.00 5.00 MOVE 7.00 MOVE 2.00 MOVE 5.00 MOVE 7.00 MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOB MOB MOB MOB MOBMIR MOBMIR MOBMI R MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMIR two welders & helper during night Rig up 273, pick up and string bridle line in derrick, pick & set blocks in derrick, install equalizer, continue cleaning traction motors (#1 mud pump), install angle iron for conduit supports on derrick ladder, install mud cleaner over pits, install fish plates on c-frame for derrick board to support finger pad-eyes, installing silt fence on bluff side of location, marking containers and positioning saa-raa acumulation areas at camp and rig. two welders & helper during night. One night welder and helper on duty. Repair exhaust stacks, remove existing flanges and two hole to straighten stacks. String cables through mud pits and place in cable trays. Finish assem bling fluid ends on mud pumps, clean up mud pump room. Working on ac module in generatyor #3, assembling bop koomey hoses. one night welder and helper on duty. One welder and helper on nights. Used crane to pick up front legs of A-legs & pin. Adjust rigging on blocks, continue work on SCR system. Install discharge (feed) piping to mud cleaner. Start fabrication on mud cleaner platform. Start installation of gas buster. Continue work on flowline installation. One welder and helper on nights. One welder and helper on nights. 9/7/2001 00:00 07:00 07:00 19:00 7.00 MOVE 2.00 MOVE MOB MOB MOBMIR MOBMIR Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group ) Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 9/11/2001 07:00 - 19:00 12.00 MOVE MOB MOBMIR 19:00 - 00:00 5.00 MOVE MOB MOBMIR 9/12/2001 00:00 - 07:00 7.00 MOVE MOB MOBMIR 07:00 - 19:00 12.00 MOVE MOB MOBMI R 19:00 - 00:00 5.00 MOVE MOB MOBMIR 9/13/2001 00:00 - 07:00 7.00 MOVE MOB MOBMIR 07:00 - 19:00 12.00 MOVE MOB MOBMIR 19:00 - 00:00 5.00 MOVE MOB MOBMI R 9/14/2001 00:00 - 07:00 7.00 MOVE MOB MOBMIR 07:00 - 19:00 12.00 MOVE MOB MOBMIR 19:00 - 00:00 5.00 MOVE MOB MOBMIR 9/15/2001 00:00 - 07:00 7.00 MOVE MOB MOBMIR 07:00 - 19:00 12.00 MOVE MOB MOBMI R 19:00 - 00:00 5.00 MOVE MOB MOBMIR 9/16/2001 00:00 - 00:00 24.00 MOVE MOB MOBMI R Printed: Remove traction motors from mud pump #1 ,rotary table & drawworks. Ship motors to Superior Electric for repair/refurbishment. String derrick climber lines in derrick, remove bad shackles and slings. Continue 12" flowline installation. Continue piping installation on mud cleaner. Start fabrication of support legs for gas buster. Continue fabrication on mud cleaner work platform. Night welder and helper. Limited night operations, one welder and helper. Rig electrician and contract electricians going through SCR system. Removed traction motors from mud pump #2 and shipped to Hayden Electric in Anchorage. Continued work on flowline spool between header and spool coming off sub. Built freight dock. Finish stringing new lines in derrick and tie back out of way. Completed fabrication of bas buster stand. Begin fabrication on gas buster U-tube. Completed winterization of outside sewage and water storage tanks and plumbing. Installed reflectorldelineator markers on entrance road from highway on curves and embankments. Walk around safety w/Rich Nelson safety. Limited night oprations, one welder and helper. One welder and helper working nights. PJSM, worked on worked on communication between the PLC system and the drillers console. Trouble shoot drawworks A & B motors. Tie off to blocks with crane, remove hook for extra head room with Tesco top drive. Once hook was off rehang blocks. Continue work on gas buster- install vent pipe. Continue work on mud cleaner, installing return line off of belly pan. vacumn mud and rainwater out of all tanks, berms and mud pits. One welder and helper working nights. Limited night operations w/welder and helper. PJSM, installing B motor on drawworks, hooking heaters up on A & C motors. Trouble shoot SCR, Install section of flowline from shaker header to sub. Begin work on flow line stand. Complete mud cleaner installation. Install mud cleaner work platform on pits. Fabricate extensions off ells on shaker header. Limited night welding. Limited night operation, one welder and helper. PJSM, complete installation and wiring of B motor on drawworks. Wire shaker motors on pits, trouble shoot lights in derrick, replace bad bulbs. Install traction motors on mud pump #2 and begin wiring. Install one traction motor on pump #1. Conplete fabrication of drops into shaker from header. Finish plate work around mud cleaner. Start fabrication on gas buster u-tube drop into shaker possum belly. Visited by SWACO rep to determine plumbing and installation of vacumn system. Attempting to find replacement for TOLOFF leaking crane. Earliest replacement - wednesday. Continued night rig up w/one welder and helper. Additional welder to begin tomorrow. PJSM, WORKING TWO TOURS WI ARRIVAL OF ALL OF SECOND CREW OR REPLACEMENTS DUE TO AIRLINES. CONTINUE WORK ON PLC COMMUNICATION IN SCR ROOM. TEST MOTORS ON DRAWWORKS. SET PUMPS IN CENTRIFUGAUSALAMANDER FEED PUMP ROOM AND SET AGAINST PITS. INSTALL SECOND TRACTION MOTOR ON PUMP #1. START FABRICATION OF 30" BELL NIPPLE. REMOVE GUN LINE UNDER CENTRIFUGE AND 5/1/2003 3:20:42 PM Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 9/23/2001 9/22/2001 9/21/2001 9/20/2001 9/19/2001 9/18/2001 9/17/2001 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 - 00:00 00:00 - 00:00 12:00 - 00:00 12:00 24.00 24.00 24.00 24.00 24.00 24.00 2.00 12.00 MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOB MOB MOB MOBMI R MOBMI R MOBMI R MOBMIR MOBMI R MOBMI R MOBMI R MOBMI R Printed: START FABRICATION ON SPOOL TO RELOCATE GUN LINE. FABRICATE STAND FOR GAS BUSTER U-TUBE. PJSM, continue trouble shooting PLC communication on SCR system, PJSM on crane picks, unload rigging, position cranes and move derrick into substructure. Leave cranes tied on for setting derrick on floor tomorrow. Install chain guard on #1 mud pump, off load new drilling line. Complete top end fabrication of 30" bell nipple. Complete and install support for gas buster u-tube. Install weather stripping around centrifuge feed pump room. Replace motor on drawworks with spare motor. Set derrick on rig floor and pin. Finish hook-up chain on #1 mud pump. Install cover and fill with oil. Start suction piping for centrifuge feed pumps. Continue fabrication on centrtifuge platform. Remove derrick guides from A-legs. ( Guides were installed as per Pyramid). Install new drlg line spool on spooling unit. Begin fabrication for pop off lines for mud pumps. Added 40 gal chain oil to #2 pump. Removed excess hoses, lines and various odds and ends from sub base. Checked drawworks tie down bolts, waterand air lines. Welders mounted centrifuge pumps and worked on centrifuge landings. Build skids for centrifuge on pits. Reshim drawworks "A" motor with crane. Electricians installed wiring for new equipment on rig. Wired up water well. Put up lights and check wiring around rig. Welder patched holes in floor of centrifigal room. Weld up high pressure pop off lines. Weld suction lines for centifuge feed pumps. Dial in drawworks traction motor "A" and bolt down same. Set beaver slide in place. Scope catwalk up and pin same. Place blocks on catwalk for string up. Install #1 mud pump liners. Work on rig water system to drawworks and brakes. Check out drawworks and brake systems. PJSM. Sring up new drlg line. RU derrick board. Continue with fab and installation of centrifuge feed and discharge lines. Run wire for derrick board. Running power to centrifuges. Install lights and check wiring around rig. Start pumping water well at 14:00 hrs @ 11 gpm. Check weight indicator system. RU air system to pits. Welders working on centrifuge pump suction and feed line plumbing. Install 7" liners in #1 and #2 pumps. Set 2 wind wall sections on back side of derrick. Prep derrick and board for raising. Raise and pin derrick. RU derrick climbers. Set air tuggers and rig lines. Stand wind walls. RD and hang bridle line. Finish tie back bridle line. Install drawworks motors blower ducts to wind walls. Install stand pipe section from sub to rig floor. MU pop offs to boilers. Remove off brand tong parts from rig. MU centrifuge feed pump suction lines and discharge lines. General housekeeping in dog house and rig floor area. Work on steam heaters and lines on rig floor. Set boom line tugger and string same. Electrician worked on rotary table motor. Start RU iron roughneck track system. Install rig floor lights. Work on V-doors. Work on mud pumps. Replace hoses on rod wash pumps and wash lines. Hang steam heaters. MU steam, air and water lines in pump room. Welders working on centrifuge fab and iron roughneck rails. Plug lod flow line holes in sub. Finish plumbing air system for pump room. Installed Sara blocks f/ crown to board and f/ board to rig floor. Remove shipping locks and pins from all shakers. Tighten up shaker manifold. 5/1/2003 3:20:42 PM 9/16/2001 00:00 - 00:00 24.00 MOVE MOB MOBMIR Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 9/30/2001 9/29/2001 00:00 00:00 2:00 - 00:00 12:00 - 00:00 12:00 2:00 2.00 2.00 12.00 12.00 MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOBMI R MOBMI R MOBMI R MOBMI R Printed: grating over mixing pit. Work on rod oilers and valves in pits. Run hydraulic hoses to iron roughneck. Plumb water lines. Test Koomey bottles. Replace one bladder. Order valves.Assist welders. Remove valves on choke manifold and place in choke house. Circulate water around pit system. Install all inspection covers with new gaskets on boilers. Weld in fittings for test pump and coolers. Plumb hoses for each. Install new relief valve for boilers. Install jet line for flowline. Con't run hydraulic lines for iron roughneck. RU snubbing line post for tongs. Tighten standpipe clamps. Modify choke house. PU slips, tongs and elevators and dress same. Install chke manifold in choke house. Plumb steam lines. Charge Koomey bladders. Plumb lines to centrifuge. Pull probes out of pits. PU kelly swivel. MU and hang Tesco torque tube. Connect 3" shock hose to #3 MP. Plumb water to shakers. Install new door seals on #1 boiler. Connect and test iron roughneck. Turn on water. Work on tong counter weight buckets. Run stroke counter lines to Swaco choke panel. Set top drive on floor with crane. Hang front wind walls and v-doors with crane. Add spacers to top drive for torque bushing. Work on pump pop offs, boiler and hydraulic unit 5/1/2003 3:20:42 PM 9/28/2001 9/27/2001 9/26/2001 9/25/2001 9/24/2001 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 12:00 2.00 MOVE 24.00 24.00 24.00 24.00 MOB MOBMIR MOBMIR MOBMI R MOBMIR MOBMIR Work on V-Doors. Lay down gator backs off pipe rack. Work on boiler blow down line. Plumb water and air lines on pits. Check out stand pipe manifold. Plumb in drain line for washing machine. Finish building iron roughneck rails. Work on mud pits, dump valves, centrifugal mud lines and valves. Work on RU of steam and water lines to mud pits. Modify and RU fill line to trip tank. General RU of rig floor and sub. General housekeeping of rig and location. Electricians wiring control board and H2S sensors and working on rig lighting. Set iron roughneck on rails, hang derrick lights and set tools on rig floor. Welders building centrifuge stand. Repair centrifugal pumps. Install modified fill up line on trip tank. Install and repair handrails on beaver slide. Install second safety chain on beaver slide. Install hatches to access sumps in mud pump area. Electricians installing methane alarms, H2S alarms, outside lights RU on Driller's doghouse and camp. Worked on centrifuges, disconnect wiring to move control boxes due to location of 2nd centrifuge. Checkout wiring and rotation of 2nd centrifuge. Troubleshoot electrical problem with shaker on mud cleaner. Scrape and paint on sub structure. Received wellhead equipment, 13 crates total. Tesco prep top drive unit for RU. Prime gas buster line. Painting exhaust stacks. Dressed location berm. Hung well sign in visible location on sub-base per AOGCC regulations. Welding in Iron Roughneck rails. Fix airline to pits. Hang top drive clamps and perform acceptance test. Re-install starter boxes on #1 centrifuge. Repaired electrical problem with mud cleaner shaker. Tested electrical on shale shakers--ok. Removed #2 centrifuge and install new centrifuge stand. Trouble shooting electrical problem on rig floor. Finished welding on iron roughneck guide rails. Berm in gas buster. Set centrifuge on rack and work on fabricating waste chute for same. Brought swivel to rig floor. Took delivery of the EPOCH well logging shack and BHI directional/LWD/MWD shack. Work continues on 9/23/2001 00:00 - 00:00 24.00 MOVE MOB MOBMIR Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 0/6/2001 0/5/2001 10/4/2001 10/2/2001 10/1/2001 0/3/2001 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 12:00 - 00:00 12:00 00:00 24.00 24.00 24.00 24.00 24.00 MOVE MOVE 12.00 12.00 MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOB MOB MOBMIR MOBMI R MOBMI R MOBMI R MOBMI R MOBMIR MOBMI R Printed: Build berm for top drive power unit. Place XO on top of top drive and make up swivel. Remove swivel from carriage. Set power unit in berm. Hook electrical to auxiliary. Rig top drive to torqe tube guide. Pull top drive hydraulic hoses over windwalls and connect to top drive. Hang hoses in derrick and lace on cover. Weld in stand for iron roughneck hoses. Assist welders. Plumb boilers. Install Tesco control panel. Cut holes for and install snubbing post. Work on Koomey bladders. Check out mud line sensors. RU fuel line and control line for Testco. Replace rod cooler lines on pumps. Install new pop off on #2 pump. Fill out and work on derrick and pit inspection. Fine tune top drive over hole. Tighten all nuts and bolts on torque tube t-bar. Install sensors in mud line. Run hose to console and charge. Blow out drawworks spear line. Commission drawworks. Installed pop off on #1 mud pump. Connect and test crown-o-matic. Lay down stand pipe. welding misc. projects, move TESCO control panel, snublime on tongs, PJSM, checked rotary rpm, air slips, water line on pit boiler, override clutch, install pop off line & valve on #3 mud pump, install bleeder valve on stand pipe manifold. Rig up cement hose from stand pipe fill line to pop off line to circulate pill pit. Put plugs in charge pumps & adjust pop off line. Test charge pump & oilers from SCR house, ok. PJSM to commission #1 & 2 mud pumps. Bermed reserve side of pits, clean pill pit & welded shut dumps. PJSM, replace bladders in koomey bottles, move truck shop, test mud pump, circulate f/suction pit. Electrical work on drillers control panel. Comission mud pumps, test #1 @ 80 spm, #2 @ 84 spm + 2700 psi wigen #1 &3,2 hrs apiece. 75% workload @ 780-790 kw. Work on stand pipe valve (oteco 4"), run #2 mp on #2 generator. #3 mud pump checked out. Lock out-tag out #1,2 &3 mud pumps. working on valve testing, comissioned #2 gen set. Rigged up bottom section of stand pipe in derrick. Working on boiler. Miscellaneous welding. PJSM, replace hammer unions on mudline, valves on charge pump. Working on stand pipe valve-change packing. Test gen #1, mud pump #2 2600 psi, 780 kw. Load up gen #3 wlmud pump. Spill drill w/CISPRI on pad for ADEC & other agencies. Work on SCR3. Load test #2 mud pump using gen #2, shut down mud pump to fix leaking cap gasket. replace cap gasket. Load test #2 mud pump wIgen #2. PJSM before commissioning #2 mud pump, test gen #2 &3. Install desander & desilter mud dumps. Commission #1 mud pump. Change out #3 mud pump pop off & commission #3 mud pump. all 3 mud pumps accepted. Replace valve cap gasket, start test on mud pump #3, stop test on pump. Tighten pony rod, adjust chains on pump #3. Start test on #3 pump, set roof on choke house. Prepare cellar to weld on drill spool. P/u stand pipe & secure w/brackets. Make up unions on kelly hose & s-pipe. Weld 30" 300# flange to conductor riser. Pull chain & chain case from #3 mud pump to replace gaskets. Replace valve in suction pit. Finish second welding pass on seal plates in mud pits. Continued fabrication work on TESCO exhaust stack. Installed flow paddle in flow line. Complete commissioning of mud pumps. Begin trenching and installation of phone and net lines to bhi and epoch trailers at rig. Begin installation of swaco vacuum system piping. PJSM, miscellaneous welding, remove pop off #1 mud pump for 5/1/2003 3:20:42 PM 9/30/2001 00:00 12:00 12:00 00:00 2.00 12.00 MOVE MOVE MOB MOB MOBMI R MOBMIR Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 0/10/2001 10/9/2001 10/8/2001 on/2001 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOBMIR MOBMIR MOBMIR MOBMIR Printed: repairs, pump water through charge pump suctions, gun lines, check valves. Raise scaffolding in cellar, put modified exhaust on TESCO hydraulic pack engine. Run hydraulic lines to choke f/floor. Workon gaurds of mud pump #3. Test pressure washer in pump room. Paint roof of choke shack. Install chain & chain case on #3 mud pump. Fabricate & install valve handles in mud pits. Fix oil leak on draworks. Change out filters on fuel pump. Seal doors on boilers. Fabricate roof cap on choke house. Continued welding on 30" conductor attaching 30" 300# flange. Continued work on cuttings tank. Fabricated stand for epoch monitor on drillers console. Ditch and install telephone & net lines to bhi, epoch and mi mud shacks. PJSM, helping welders, check derrick air tugger. Seal off rig floor. Inventory rig supply and parts. Test #3 mud pump oil seal. Prepare pipe rack f/welder. Change out suction valve on desander pump. Replace two lights in derrrick. Fill Koomey wloil. Get ELMAGO brake working and adjust brakes on drawworks. Clean rig floor & off side dog house. Work on getting boilers ready to fire. Continue work on cement line to floor f/sub. Finish fabricating supports. Continue fabricating pipe spools. Modify driller's console to enable full vision of floor. Working on bell nipple and 30" conductor/riser. Repaired spear on drawworks. Installing fuel meters on boilers. Repair suction valves in pits. EPOCH finishing wiring on monitors and pit levels. Prepare north end of pad for cook shack & generator. Plumbing vacuum lines. PJSM, assist welders, plumb air to choke controls and air slips, water to centrifuges, work on boilers, hook up TESCO control panel, work getting derrick board ready. Set DOWELL cement tanks. Torque top drive to swivel. Paint mud dock, snubbing posts & steam lines on fig floor. Set amp limits on generators 1thru 4. Replace pulleys on risers in suction pits. Paint deck on suction pits. Start installing cement line. Recieved new 30" beveler, weld 30" landing ring to top section of conductor. Electrician working on power limits and load sharing for gen sets. Plumbing steam, air and water to rig floor. 30" bell nipple completed and ready to install. PJSM, top weld of 20" landing ring in 30" conductor completed. 3" cement line to floor 25% complete. Current limits on the mud pump traction motors adjusted to 800 amps per motor. Continued work on vacuum system, vacuum unit due in today. Sidewinder mud hopper mounted on pits. Plumbing will start next on sidewinder. Torqued quill on swivel to TESCO top drive. #1 boiler running. Assist welders, cut holes f/vac system to floor, M/U hose, m/u water-steam manifold to floor. Pin brake out sub sub post. Install sheeves for risers in pit. M/U quill & swivel to 48k. Install mud hopper, plumb & calibrate weight indicator, line pull, pump pressure & hydraulic choke gauges by quadco. Run lines fror totco drilling recorder & quadco serviced recorder. Set crown-o-matic, General housekeeping. PJSM, blow down steam lines w/air, bring #1 boiler to high fire. R/U chemical barrel on pits. Safety line for kelley hose. R/U valves on steam lines. String up totco drilling recorder. Change out steam valves. Fire watch & help welders bevel cut & grind 30" conducter in cellar. Change out desilter pump. Bolt up landing ring flange to diverter line spool. Paint stabbing board. Plumb pop- off lines to h20 tank on #2 boiler. Bolted diverter spool to 30" conductor, will lower on 30· stump in cellar to verify location of diverter line coming out of substructure. 5/1/2003 3:20:42 PM 0/6/2001 00:00 - 00:00 24.00 MOVE MOB MOBMIR Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date End: Group: ') 8/30/2001 10/15/2001 10/12/2001 10/11/2001 0/14/2001 0/13/2001 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 24.00 24.00 24.00 24.00 24.00 MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOBMIR MOBMIR MOBMI R MOBMIR MOVE Printed: Repaired lights inside substructure. Fabricated rig floor connection for the mujd bucket. Began the piping installation on the sidewinder hopper. Finished welding 30" conductor. Worked on #2 boiler burner, boiler firing correctly but had some leaks in gasketing. N/U remaining valves on choke manifold and installed sensator and pressure gauges. Blow down water in steam lines and pumps to pits. Adjust kelley hose. Set vacuum system and plumb to vac lines. M/U 4" flare line valve on choke manifold. Plumb in super choke lines & pressure test. Continued work on cement line to rig floor. PJSM, welder continuing work on cmt line & install to rig floor. Change out all shaker screen lock down bolts to quick release nuts, installed pop off line f/#2 boiler to water tank. Finish adjusting kelly hose & install safety clamps w/safety cables. Purged dp pressure & csg pressure lines w/koomey fluid to super choke control panel. #2 boiler on line & heating rig. Fix steam leaks & replace bad valves most on the steam traps are bad or missing discs. M/U xo to topdrive & torque. Change out 2-8" valves in pill pit. Fuel light plants & camp generator. Bolts arrive for N/U bop, after cement line is finished installing will n/ul diverter and annular. Charge pump #3 is back together along wI the desilter and desander pumps, mechanical seals in all three replaced. Continued changing bad butterfly valves on suction line in pill pit. cuttings tank for shaker finished installing skid. Began erection of Global catering kitchen. Hauling water from gravel pit 9 miles away up North Fork Anchor river. 50 minute round trip time. PJSM, fire watch & help welders, continued to work on steam leaks, continued installation cement line to rig floor. Continued replacing 8" suction valves in pill pit. Install 30" api ring between conductor flange & diverter flange, p/u 30" annular preventor & m/u to diverter riser. Attempted to install 30" drilling nipple on hydrill, wouldn't mlu, lay down nipple & modified flow line on nipple. Nipple up riser on hydrill & m/u dresser sleeve for flow line. Check & set load sharing on all 4 generators. Install quick locks on #2 derrick shaker. Fuel all equipment. Installed exhaust stack on #1 boiler. Continued rigging up catering tent. PJSM, change out 8" suction valve in pit #4, finish w/turnbuckles on 30" annular. Turned diverter knife valve over flproper seat. Clean & put away excess tools f/cellar area. RIu air tuggers on rig floor w/proper swivels chains & hooks. Work on diverter hydraulic lines. Set master bushing & iron rough neck railing in place. Rig down plu sling to cat walk. Set desilter & desander cutting tank. Laid herculite and matting board, set mud cleaner & centrifuge cuttings tank. Build berms for above and base oil storage tanks. Fuel equipment, PJSM, set & berm cutting tank for shale shakers. Make up hydraulic accumulator lines to hydrill knife valve. Replace 8" butterfly valves in pump room & pits #3 & 4. Installed framework for boards in setback support pans on rig floor. Started installation of mud bucket line. Completed wiring of gas sensor system. Welding on mud sidewinder hopper. Installing extra steam heaters in choke house & centrifuge feed pump house. Continued installation of catering tent. PJSM, fire watch & helping welders, plumbing water to shakers, modify cellar door f/diverter line. MIU 40' diverter line section to knife valve outward from cellar. Working on plumbing hole fill, stand pipe bleed off 5/1/2003 3:20:42 PM 10/10/2001 00:00 - 00:00 24.00 MOVE MOB MOBMIR Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 0/21 /2001 0/20/2001 00:00 - 02:00 00:00 12:00 - 00:00 2:00 - 00:00 12:00 2.00 DRI LL 2.00 12.00 12.00 MOVE MOVE MOVE PULD COND1 MOB MOB MOB MOBMI R MOBMIR MOBMIR Printed: Circ all 3 mud pumps w/ returns to pits. Work on #1 pump discharge valve. Tighten up swivel packing. PJSM, change out swivel packing. Test TO, stand pipe, mud line and pump discharge valves to 5000# OK. Blow dn TO and mud lines. Install grateing over cellar.Calibrate EPOCH Remove recorder from dog hse. repair heater. Change pulsation dampener to 750#. Re.wrap service loop. Rig up for air slips. screen up 3rd shaker.Hang hoses for pipe rack drains Finish hanging drip pan hoses. Seal off drip. Trip off trip hose. Secure small mouse hole. Clean up cellar area. Cont' mix spud mud. Finish install air slip control. Adjusted geolgraph line in derrick. Installed new vacumm plate and mechanical pkg in desander pump. Install drillers side tugger sheve at the board. RU break out line for tongs. Set air dryer in moter room. Install valve to pump liner wash line. MU lay down line. Work on berms around v-door slide and cuttings tank. Finish berms at rig and cuttings tank. Run hydraulic line to tong torque sensor and test same. OK. Finish RU lay down line. RU mud bucket. RU to to PU HWDP. PJSM and HWDP handling. PU and stand back 5" HWDP. Rabbit and 5/1/2003 3:20:42 PM 0/19/2001 0/18/2001 10/17/2001 10/16/2001 00:00 00:00 00:00 00:00 12:00 - 00:00 2:00 - 00:00 2:00 - 00:00 2:00 2:00 2:00 2:00 12.00 12.00 2.00 2.00 2.00 2.00 MOVE 2.00 MOVE MOVE MOVE MOVE MOVE MOVE MOB MOB MOB MOB MOB MOB MOB MOBMIR MOBMI R MOBMIR MOBMIR MOBMI R MOBMIR MOBMIR and bell nipple returns to trip tank return. Set pipe racks to catwalk off drillers side. Off load trucks w/5-1/2 drillpipe. Fuel light plants, welders, air heaters & forklift. Installed pop off to #1 mud pump. Work on jet line to flowline, outside cellar windwall above the pump room. Install boards and grating for racking table on rig floor. Plumb jet line in flowline. Install pull back lines, tie back ropes for drillpipe & belly rope on racking board. Hang mud cleaner chute. Plumb caustic barrel. Fuel equipment. Continued cement line project. Calibrate gas sensor alarms. Set mouse hole in place. Working on koomey air pumps. Finish fabricating the mix discharge line for sidewinder hopper. Fabricated dumps off of desilter and desander. Continued installation of catering camp. Assist welders with pipe rack modification for diverter line. Con't with pit water system plumbing. Work on flowline jet lines. Install pump belt stripping for rig floor pipe rack. Hang trip tank return line and mud bucket dump in cellar. Install last joint of 16" diverter line. Change out 6' butterfly valves in pump room. Mount cameras in cellar. shale shakers and derrick board. Install bird bath under rotary table. Fuel all equipment. Anchor diverter line. Cont' shaker modification. One welder working on HSE issues ( eye wash stations and safety chains) Clean up the area. Finish laying down pump belting on rig floor pipe rack. Finish mud bucket dump line and trip tank return IineRemove and modify drip pan from cellar. Clean snow from walkways and landings. work on jet lines. Plump air to rig floor for blow down manifold. work on air lines to trip tank return line air valve. adjust bleed-off line on standpipe. Mix spud mud. Install pedal for air slips. Plumb 2" air line to rig floorto blow down kelly hose and top drive Adjust trip tank return line. Install drip pan. Work on steam heaters. Set mouse hole. PU 2 jts 5" HWDP for diverter test. Hook up squawk boxes around rig. Function test diverter. System closed OK. Slow to recharge system. Install sensors on mud line. Change out saver sub on top drive. Screen up shakers. RU blow down line for stand pipe. Pump slow through shakers. 10/15/2001 00:00 - 00:00 24.00 MOVE MOB MOBMIR Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 10/24/2001 2:00 14:30 5:00 22:00 00:00 01:30 03:00 04:00 05:30 06:00 6:00 - 22:00 14:30 15:00 21:00 00:00 01:30 03:00 04:00 05:30 06:00 2:00 2.50 CASE 0.50 CASE 6.00 CASE 2.00 DRILL CIRC COND1 1.50 DRILL URM COND1 1.50 DRILL TRIP COND1 1.00 DRILL PULD COND1 1.50 CASE RURD COND1 0.50 RIGMNT RSRV COND1 6.00 CASE RURD COND1 COND1 6.00 DRILL URM SFTY COND1 SFTY COND1 RUNC COND1 14:00 15:30 01:00 01:30 2:00 2:30 3:30 10/23/2001 21:30 00:00 01:30 12:00 18:30 19:00 22:30 00:00 00:30 00:00 01:30 12:00 18:30 19:00 22:30 00:00 00:30 01:00 2.50 DRILL 1.50 DRILL 0.50 DRILL 6.50 DRILL 0.50 DRILL 3.50 DRILL 1.50 DRILL 0.50 DRILL 0.50 DRILL PIL T COND1 PIL T COND1 PIL T COND1 PIL T COND1 CIRC COND1 TRIP COND1 PULD COND1 URM COND1 URM COND1 Printed: Open hole from 17 1/2" to 24" f/ 470' to 560' Tesco checked to make sure no bolts had backed off in pipe handler. Noticed that grabber assembly was too high and adjusted same. Open hole from 171/2" to 24" f/ 560' tov 706'.4' of 17 1/2" hole below cutters. Circ and condition mud. Pump hi densityl hi vis sweep. Pump hi density I hi vis sweep. No increas in cuttings observed. POH. No problems. LD 24" BHA. Clean rig floor and change out bales. Service rig. RU to run 20" csg. Clean out trip tank for cement job. Modify 16" knife valve to be use during cemnet job. Layout 10" pipe for diverter line extension. Safety stand down. PJSM on running 20" csg assisted by crane. RIH with 17 jst 20" 104# X-52 csg. Work through several tight spots. No problems Drlg 171/2" pilot Drlg 171/2" pilot Circ hole clean. POH. No problems. LD 17 1/2" bit and stab. MU 24" HO and stab. Welder working on removing pin from master bushings. Tesco repaired fitting and replaced hydraulic hose on top drive elevators. RIH wI 24" hole opener to 44'. Open hole from 17 1/2" to 24" f/ 44' to 470'. CBU. Set back 1 std. Had small leak in gooseneck. Tighten thread half on Tesco goose neck extension. Troubleshoot Testco top drive. Had sparks coming from bottom of sub. 5/1/2003 3:20:42 PM 5:30 6:00 01:30 12:00 12:30 13:30 14:00 .50 DRILL 0.50 DRILL 0.50 DRILL 10.50 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL URM URM TRIP URM CIRC URM URM COND1 COND1 COND1 COND1 COND1 COND1 COND1 load hole hole from from 107' 480' to 480' to 710' 10/22/2001 18:00 20:00 21:00 08:30 11:30 12:00 5:00 14:30 20:00 21:00 21:30 5:00 11:30 12:00 14:30 18:00 2.00 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 0.50 DRILL 2.50 DRILL 3.00 DRILL 0.50 DRILL PILT CIRC PILT SFTY PULD COND1 OTHR COND1 OTHR COND1 PILT COND1 COND1 COND1 COND1 COND1 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 06:30 06:30 - 08:00 08:00 - 08:30 2.00 DRILL 1.00 DRILL 1.00 DRILL 2.50 DRILL 1.50 DRILL 0.50 DRILL PULD COND1 PULD COND1 PULD COND1 PULD COND1 OTHR COND1 SFTY COND1 Finish loading floor with BHA jewelry and tools. Cont' PU and stand back 5" HWDP and jars. Total of 29 jts HWDP. Clean all walkways, stairs and landings of excess snow and ice. Held pre-spud safety meeting with all personnel. Discussed divert operations. MU BHA. Break circulation. Check all surface equipment. Check surface equpment. Run all pumps and tighten all leaking connections. Held pre-spud safety meeting with all personnel. Discussed divert operations. Had crew change at noon. Drlg 17 1/2" Hole from 44' to 103'. Hole sloughing on connection while still in drive pipe. Suspect improper flow rate. Trouble shoot pumps. Repair 2 pop off valves. Circ hole clean. Make connection w/ DC. Drlg 171/2" hole from 103' to 107'. Gates leaking on shakers and slide backing up with cuttings. Modify shaker discharge and cuttings chute. 10/21/2001 strap same. Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ') Attempt to land csg in BWS with no succes. Unable to work landing ring through diverter spool. Suspect 10 restriction in spool. Pull landing ring to floor and cut off same. Replace landing ring with a 20" centralizer. RIH with csg. Shoe at 698'. RD csg tools and RU to run 5" HWDP. Finish RU to RIH wI stab in tool and 5" HWDP. RIH wI 5" DP to 622'. Change out bales. MU circ head to HWDP. No 5" manual elevators on location. Did not run centralizer on 1st jt of HWDP. Change out bales. Prep to POH. POH wi HWDP. Install centralizer. Remove saver sub and top drive bell guide to add distance between elevators and grabbers. RIH wi HWDP. RU 51/2" equipment. MU 51/2" pup jts. Strip on 20" flow adapter. Break circulation. Spot 20 bbls treated mud above float collar. Sting into float collar. Circ and condition mud while RU cement dump line on diverter line. Circulate at 8 bpm at 300 psi. RU Dowell. PJSM on cementing csg. Pump 10 bbls preflush. Test lines to 3500 psi. Pump 30 bbls preflush, 140 bbls lead cement (divert to reserve pit), 65 bbl tail anf 5 bbls FW. CIP at 16:04 hrs. Flush out diverter equipment. Pul out of float collar. Circulate through HWDP to clear pipe. POH wi 5" HWDP. WOC. Clean out diverter line. NO diverter line to cleanout cement while WOC. Change out valves on desander line. Rd drip pan, flowline and trip tank kine. Prep to cut 20" csg. PJSM. Rough cut 20" csg. NO diverter system. Check 30" 600 flange on top of diverter spool for restrictions. Flange had a 27". API dimensions should have been 30". Cut off 30" csg. Final cut 20" stub. Set well head in place. Not enough weight to force head over seals. NU diverter spool and diverter to force well head. Tighten slip on well head to grip 20". Test seals to 350 psi for 30 min. OK. NU diverter spool, diverter, bell nipple, drip pan and all related hoses and equipment. RU floor to pick up 51/2" DP. RU Weatherfords lay down machine. PJSM on PU DP. Function test diverter system after modification. PU and stand back DP. EPOCH spear recorder fell off drawworks spear. Replace same. PU 5 1/2" DP with lay down machine and stand back in derrick. Function test diverter and gas detection system. Test witnessed by AOGCC rep John Spalding. PU 5 1/2" DP with lay down machine and stand back in derrick. Total of 73 stds in derrick. 15:30 16:30 18:00 - 16:30 8:00 9:30 .00 CEMENT RURD COND1 .50 CEMENTTRIP COND1 .50 CEMENTTRIP COND1 RD lay down machine. RIH with 13 1/2" slick BHA. Repair crown-o-matic. Printed: 5/1/2003 3:20:42 PM 0/28/2001 0/27/2001 0:00 6:30 8:30 21:00 21:30 22:30 23:30 00:00 09:00 01:00 17:30 - 00:00 00:00 5:30 18:30 21:00 21:30 22:30 23:30 00:00 09:00 0:00 01:00 6:30 5.50 CEMENT PULD 2.00 CASE RURD COND1 2.50 CASE RURD COND1 0.50 CASE SFTY COND1 1.00 CASE OTHR COND1 1.00 CASE OTHR COND1 0.50 CASE OTHR COND1 9.00 CEMENT PULD COND1 .00 CEMENT SEOT COND1 5.50 CASE .00 CASE 6.50 CASE NUND COND1 NUND COND1 NUND COND1 COND1 10/26/2001 04:00 2:00 7:30 8:30 00:00 6:00 12:00 17:30 18:30 00:00 04:00 17:30 8.00 CASE 5.50 CASE .00 CEMENTOTHR COND1 5.50 WAlTON CMT COND1 4.00 CASE NUND COND1 .50 CEMENTOTHR COND1 NUND COND1 NUND COND1 3:30 14:00 07:00 08:00 09:30 10:00 - 14:00 16:00 08:00 09:30 10:00 3:30 0.50 CEMENT SFTY COND1 2.00 CEMENT PUMP COND1 .00 CASE OTHR COND1 .50 CASE OTHR COND1 0.50 CASE OTHR COND1 3.50 CEMENTCIRC COND1 10/25/2001 05:30 - 06:30 06:30 - 07:00 22:30 00:00 00:30 02:30 00:00 00:30 02:30 05:30 .00 CASE 0.50 CASE .50 CASE 0.50 CASE 2.00 CASE 3.00 CASE OTHR COND1 OTHR COND1 RURD COND1 RURD COND1 OTHR COND1 OTHR COND1 0/24/2001 21:00 22:30 .50 CASE RUNC COND1 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: Printed: 5/1/2003 3:20:42 PM 11/3/2001 00:00 - 01 :30 01 :30 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 23:30 23:30 - 00:00 11/4/2001 00:00 - 00:00 11/5/2001 00:00 - 11 :30 11 :30 - 13:00 11/1/2001 11/212001 0131/2001 0/30/2001 0/29/2001 9:30 20:00 20:30 00:00 01:30 03:00 04:00 07:30 08:30 21:00 22:00 23:30 00:00 02:30 12:30 14:00 00:00 03:30 05:30 07:30 09:00 10:00 11:00 12:00 00:00 00:00 06:30 08:00 14:00 16:00 20:00 20:00 20:30 00:00 01:30 03:00 04:00 07:30 08:30 21:00 22:00 23:30 00:00 02:30 12:30 14:00 00:00 03:30 05:30 07:30 09:00 10:00 11:00 12:00 00:00 00:00 06:30 08:00 14:00 16:00 20:00 00:00 11.50 DRILL .50 DRILL .50 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 4.50 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 1.50 DRILL 1.50 DRILL 3.50 DRI LL 0.50 DRILL 24.00 DRILL 0.50 CEMENTTRIP COND1 0.50 CEMENTCIRC COND1 3.50 CEMENT DSHO COND1 1.50 DRILL DRLG SURFAC 1.50 DRILL CIRC SURFAC 1.00 DRILL TRIP SURFAC 3.50 DRILL PULD SURFAC 1.00 DRILL DEaT SURFAC 2.50 DRILL RIRD SURFAC 1.00 DRILL PULD SURFAC 1.50 DRILL OTHR SURFAC 0.50 DRILL TRIP SURFAC 2.50 DRILL OTHR SURFAC 0.00 DRILL DRLG SURFAC 1.50 DRILL DRLG SURFAC 10.00 DRILL DRLG SURFAC 3.50 DRILL DRLG SURFAC 2.00 DRILL CIRC SURFAC 2.00 DRILL TRIP SURFAC 1.50 DRILL OTHR SURFAC 1.00 DRILL TRIP SURFAC 1.00 DRILL REAM SURFAC 1.00 DRILL OTHR SURFAC 12.00 DRILL DRLG SURFAC 24.00 DRILL DRLG SURFAC 6.50 DRILL PIL T SURFAC 1.50 DRILL CIRC SURFAC 6.00 DRILL TRIP SURFAC 2.00 DRILL TRIP SURFAC 4.00 DRILL PULD SURFAC 4.00 DRILL DEaT SURFAC DRLG CIRC TRIP SURFAC OTHR SURFAC OTHR SURFAC OTHR SURFAC OTHR SURFAC DEaT SURFAC TRIP SURFAC TRIP SURFAC PULD SURFAC PULD SURFAC OTHR SURFAC TRIP SURFAC DEaT SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC DRLG SURFAC DRLG SURFAC SURFAC SURFAC twice. Drilled f/4626-5113' Circulated two bottoms up. RIH to top of float collar at650' Establish circulation. Circulate out cement contaminated mud. Drill out FC, cement and new formation to 718'. Drlg 131/2" hole. Circ and condition mud. POH with bit. MU Autotrack tools. Shallow test Autotrack tools. Finish welding mud gate and cuttings chute on #4 shaker. MU BHA. Calibrate BHI and Epoch equipment. RIH to TO. Weld on new shaker, change elevator inserts to 5-1/2. RIH w/1st std 5-1/2 DP, Drill f/727-1166', started kickoff @ 800' TESCO IOBP valve malfunction-electrical. Drld f/1166-1719'. Drld f/1719-1904', survey. Circulating while evaluating top drive actuator valve. Check for flow, poh to shoe to work on top drive. Work on roto actuator valve of top drive. Rih. Wash & ream, downlink auto track. Work on mud pump SCR Drld f1904-2556' Drilled f/2556'3422' 18.8 hrs ADT. Drilled 13-1/2" pilot hole f/3422-3587'. 5.9 hrs ADT. Circulate bottoms up twice to clean up hole. Poh flbit based on hours (50.9 hrs) and penetration rate. Download BHI Autotrak information. Lay down, pick up and make up BHI LWD BHA to float sub. Test Autotrak & load source in neutron density sub. Unloaded 585 bbl base oil into upright storage tanks. Rih w/jars & hwdp, strap hwdp. pjsm, slip & cut drilling line. lubricate rig. Work on reverse in SCA. Repair broken chain on grabber; change out elevators TIH and test BHI Autotrack; test failed POOH one stand, blow down top drive TOOH to Autotrack and download source LD 3 - 8" DC's; PU 3 - 6-5/8" NM Flex DC's Load ON Sources Install Keepers in pins on OW brakes TIH w/5" HWDP & 1 jt of 5-1/2" HT-55 DP Kelley up and test Auttrack and LWD - OK TIH to 2140'; small cuttings bed @ 2140' Wash cuttings bed buildup from 2140' - 2289' Rih to 3587'. Drilled f/3587-3592'. Drilled f/3592-4626' ADT 7.35 hr. Changed grabber dies on top drive 0/28/2001 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 9:00 20:30 20:30 21:00 .50 DRILL 0.50 DRILL PULD SURFAC TRIP SURFAC Printed: for new HO run. Make up new bull hole opener and weld tabs at connection. PU 17-1/2" hole opener BHA and RIH RIH to float collar and tagged w/8M. Attempted to rotate and had high 5/1/2003 3:20:42 PM 09:00 10:00 11:00 0:00 11 :00 9:00 .00 DRILL .00 DRILL 8.00 DRILL OTHR SURFAC OTHR SURFAC OTHR SURFAC bit. LD PDC hole opener off rig floor. same. Pull float and float sub Lay down stabbing board from derrick Servo rig WO 17-1/4" stabilizers nose to PDC 06:00 01 :00 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 06:00 09:00 3.00 DRILL .00 DRILL .00 DRILL 0.50 DRILL 2.50 DRILL OTHR SURFAC OTHR SURFAC OTHR SURFAC PULD SURFAC TRIP SURFAC Break out undergauge stabs and LD Load new BHA to rig floor PU 17-1/2" bit to run through float equipment. RIH w/bit to 726' - did not see anything. POOH w/BHAand LD 7-1/2" 11/11/2001 11/9/2001 11/10/2001 11/8/2001 11/7/2001 11/6/2001 00:00 - 09:30 9.50 DRILL TRIP SURFAC Circulated two bottoms up. POh, tight hole-swabbing, pump out f/diameter of accutrak stabilizer. Poh slowly, using mud pump, tight hole. CBU @ 2150', unloaded cuttings from tangent section. Change elevators for bha. Down load sources. Lay down stabilizer, float sub & drill collars. Down load truetrak mwd. Lay down bha-autotrack, map sub, neutron sub, density sub, stop sub & stabilizer. Pick up bha #5 & make up 17-1/2" hole opener, 2 stabilizers and pony collar. RIH w/bha & hwdp, change out elevator 5-1/2" inserts for drill pipe, rih, tag float collar @ 650'. Service rig and top drive Mud Pump #3 bad rheostat. Drill out float shoe and collarat 698' Open holefrom 698-761 P/U 65K, S/O -68K Opening surface hole f/13-1/2 to 17-1/2" f671-2352', ADT 16.9 HRS, AVG ROP =99.5'/HR Open hole f/13-1/2" to 17-1/2" f/2352-2820'. Change saver sub on top drive, stand back in derrick. Open hole f/2820-3007'. Circulate hole clean f/short trip. Work on TESCO top drive grabber and torque limit. Poh f/short trip 5 stands, no drag, hole swabbing, RIH to bottom. Open hole f/3007 -3040' Open hole from 3040 to 4419 ADT 17.25 Open Hole from4419 to 5191 ADT 6.2 hrs Circ and condition mud to run casing POOH to run 13-3/8" casing MU Tam port collar shifting tool on stand of DP Stand back HWDP and LD BHA Finish POOH w/BHA, LD PDC Hole Opener, & both stabs (HO and straight blades were 13-9/16" 00 - -4" under gauge) Clean floor 00:00 10:00 11 :00 16:30 18:00 19:30 23:30 00:00 00:00 09:00 14:30 21:30 22:00 00:00 0:00 11:00 16:30 18:00 19:30 23:30 00:00 00:00 09:00 14:30 21:30 22:00 00:00 01:00 0.00 DRILL 1.00 DRILL 5.50 DRILL 1.50 DRILL 1.50 DRILL 4.00 DRILL 0.50 DRILL 24.00 DRILL 9.00 DRILL 5.50 DRILL 7.00 DRILL 0.50 DRILL 2.00 DRILL .00 DRILL URM SURFAC OTHR SURFAC URM SURFAC CIRC SURFAC OTHR SURFAC OTHR SURFAC URM SURFAC URM SURFAC URM SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC TRIP SURFAC PULD SURFAC 9:30 20:30 23:30 00:00 09:30 11 :00 11:30 12:00 13:30 17:00 5:00 20:30 23:30 00:00 00:00 7:00 11:00 11:30 12:00 13:30 15:00 19:30 .00 DRILL 3.00 DRILL 0.50 DRILL 24.00 DRILL 2.50 DRILL 2.00 DRILL .50 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL .50 DRILL URM URM URM URM TRIP OTHR SURFAC PULD SURFAC PULD SURFAC PULD SURFAC PULD SURFAC PULD SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC 14:30 17:00 17:30 19:00 20:00 17:00 17:30 19:00 20:00 00:00 2.50 DRILL 0.50 DRILL 1.50 DRILL 1.00 DRILL 4.00 DRILL OTHR SURFAC TRIP SURFAC DRLG SURFAC CIRC SURFAC TRIP SURFAC of Poh to 4620' for mad pass logging run, tight hole 2nd stand off bottom-swabbing. Kelley up and pump out of hole. Make mad pass logging run w/oriented GR f/4620-4680' Rih to 5113' Drilled f/5113-5191' to casing point T.D. hole f/4545' Swabbing 11/5/2001 3:00 14:30 .50 DRILL WIPR SURFAC Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 11/18/2001 01:30 05:00 18:30 23:30 00:00 01:00 02:30 05:00 12:00 15:30 05:00 12:00 15:30 18:30 2.50 FISH 7.00 FISH 3.50 FISH 3.00 FISH CIRC TRIP PULD TRIP SURFAC SURFAC SURFAC SURFAC 11/17/2001 11/15/2001 11116/2001 11/14/2001 11/13/2001 11/12/2001 05:00 07:30 23:30 00:00 01:00 01:30 5:30 - 16:00 6:00 - 19:30 9:30 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:30 17:30 18:30 19:30 00:00 00:30 02:00 00:00 00:00 02:30 06:00 10:00 10:30 17:00 00:00 06:00 08:30 23:00 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 00:00 .00 DRILL .50 DRILL .50 DRILL 21.00 DRILL PULD SURFAC PULD SURFAC TRIP SURFAC URM SURFAC connector. RIH wI fishing assembly to 5110'. No problems. Circ and condition mud. Finish circ and condition mud. Work over top of fish at 5182' to 5190' with slow pump rate. Set down 25k wt with slow rotary to collapse fingers. POH wet. No problems. LD fishing tool assembly and fish. One bull nose weld strap left in hole. type cutters. Open hole to 17 1/2" fromn 3194' to 3410' Pump sweep. Circ hole clean. POH slow. Intermittant tight hole and swabbing due to clay balls. Worked through with no problems. Clean up stabilizers and hole opener. Attempt to change cutters on hole opener. Broke lock pin. LD hole opener. MU new hole opener and bull nose. Strap weld bull nose to hole opener. RIH with PDC hole opener to 2194' Finish TI H to 3194 Precautioary wash and ream from3194-341 0 Open hole to 17-1/2" from 341 0-4280 Open hole 17 1/2" from 4280' to 5070'. Open hole to 17 1/2" from 5070' to 5188'. Pump nut plug I soap sweep. Circ and condition mud to run csg. POH to 2896'. No problems. Monitor well. Pump dry job. POH. Bottom of HO has broken off leaving triangular section, weaar guard and bull nose in hole. Overall length is 6.60'. Lay down hole opener assembly and stabilizers. Stabs were .25 UG, HO was 2.5" UG. Service rig. MU 171/2" bit and stabilizer assembly. Change out top drive saver sub TIH Begin to clean out (W &R) @ 4992' Wash and ream to 5039'. Repair Tesco top drive unit. The fuel I water seperator bowl broke. Wash and ream to 5182'. Run light weight on bit. No increase in torque. Would not drill off. Called 5182' top of fish. Circ 2 bottoms up to clean hole. Monitor well. Pump dry job. POH. LD 17 1/2" bit and stab's. No problems. PU 133/8" poor-boy overshot fishing assembly. Trouble shoot Tesco top drive electrical system. Locate short torque; decided to POOH wlPDC HO Rotated less than 30 sec. POOH wlPDC hole opener. Had several broken cutters on each lead row (hole opener still in gauge) Change out bullnose to mill tooth hole opener and weld straps to same. Weld on straps f/hole opener bull nose. rih w/17-1/2 hole opener bha to 659' Wash and ream f/659'-3194' 15.71 hr ADT. Hole appears to be in gauge initially and slowly becoming out of gauge. No torque apparent at float collar in 20" casing. Hole opener is conventional wheel tooth Printed: 5/1/2003 3:20:42 PM 3.50 FISH 2.50 FISH 5.00 FISH 0.50 FISH 1.00 FISH 0.50 FISH TRIP SURFAC PULD SURFAC TRIP CIRC CIRC FISH SURFAC SURFAC SURFAC SURFAC in cable 3:30 8:30 19:30 00:00 00:30 02:00 00:00 00:00 02:30 06:00 10:00 10:30 13:30 7:30 06:00 08:30 17:00 15:30 0.50 DRILL 3.50 FISH 1.00 FISH 2.50 FISH 1.00 FISH 0.50 FISH 0.50 FISH .50 FISH .00 DRILL .00 DRILL 4.50 DRILL 0.50 DRILL 1.50 DRILL 22.00 DRILL 24.00 DRILL 2.50 DRILL 3.50 DRILL 4.00 DRILL 0.50 DRILL 3.00 DRILL 0.50 DRILL 6.00 DRILL 2.50 DRILL 8.50 DRILL 2.00 DRILL OTHR SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC TRIP SURFAC PULD SURFAC OTHR SURFAC TRIP SURFAC TRIP SURFAC URM SURFAC URM SURFAC URM SURFAC URM SURFAC CIRC SURFAC TRIP SURFAC OTHR SURFAC TRIP SURFAC URM CIRC TRIP PULD OTHR SURFAC SURFAC SURFAC SURFAC SURFAC 21:00 23:00 2.00 DRILL TRIP SURFAC 11/11/2001 20:30 21:00 0.50 DRILL TRIP SURFAC to avoid damaging same. Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) Printed: 5/1/2003 3:20:42 PM 22:00 - 00:00 2:00 22:00 2.00 0.00 WELCTL BOPE WELCTL OTHR SURFAC SURFAC pits. Open all doors. I stall 5 1/2" pipe in upper ram, blinds in middle ram and 51/2" in lower rams. Close doors. Finish cleaning pits. Load out diverter. Install landing on upright base oil tanks. Finish tighten ram doors. Install Koomey lines and function test all rams. RD slings. RU DP equipment. Install mouse hole. Install 5 test jt. Test annular to 250 - 2000 psi. Test upper pipe rams, floor valve and 3 12" 06:30 12:00 5.50 WELCTL EaRP SURFAC 11/21/2001 20:00 00:00 03:00 03:30 05:00 06:00 06:30 02:00 - 03:00 00:00 - 00:30 00:30 - 02:00 11/20/2001 11/19/2001 19:00 21:00 08:30 - 09:00 09:00 - 12:30 05:00 - 07:30 07:30 - 08:30 08:30 - 10:00 10:00 - 15:30 15:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 08:30 8:00 - 20:00 00:00 06:30 03:30 05:00 06:00 06:30 18:00 12:30 4.00 6.50 0.50 CEMENT PULD SURFAC 1.50 CEMENT TRIP SURFAC 1.00 CASE NUND SURFAC 0.50 CASE OTHR SURFAC 11.50 CASE NUND SURFAC .00 CEMENTOTHR SURFAC 0.50 CEMENTCIRC SURFAC .50 CEMENT PUMP SURFAC 21:00 00:00 9:00 2.00 CASE CASE NUND SURFAC WELCTLNUND SURFAC NUND SURFAC 2.00 CEMENT PCLR 3.00 CEMENT PCLR 0.50 CASE 3.50 CASE 2.50 FISH 1.00 CASE 1.50 CASE 5.50 CASE 6.50 CASE 1.00 CASE 1.00 CASE 8.50 CASE 6.50 CEMENT PUMP SURFAC CIRC CIRC PULD SURFAC OTHR SURFAC RURD SURFAC RURD SURFAC RUNG SURFAC CIRC SURFAC RUNC SURFAC RUNC SURFAC SURFAC SURFAC SURFAC SURFAC held. Break off cement head and RIH wrr AM combo tool @ 990' Locate into port collar, pressure up on tool, rotate to left to open and circulate @ 6 bpm through tool. CCM taking returns to cellar - haul to WB cell to reduce volumes. Finish circ and condition mud. PJSM. Test lines to 3000 psi. Pump 20 bbls h20 with one gal red dye, 145 bbls 12.5 lead cement, 20 bbls 15.8 cement and 21.7 bbls h20. Approx 45 bbls cement to surface. Close Tam port collar. Pressure to 1000 psi to verify closure. Pull cups above port collar and shear out ball at 2200 psi. Flush pumps, lines and DP with 45 bbls of treated water. RD cement lines. LD pump in sub, TIW and pup. POH wi Tam combo tool. Break out and lay down landing jt. Clear floor of excess equipment. Continue cleaning pits. LD mouse hole. RD diverter equipment. RU BOP trolly system. Remove diverter from cellar. Install pack off. NU 203/4" 3000 psi by 135/8" well head. Test packoff to 3000 psi. OK. NU BOPE. Finish NU BOP stack. Install choke, cleaning kill and HCR ines. Cont' ( 8" X 2" X 1/4") Clear floor of all 171/2" equipment. PJSM. Remove iron roughneck rails. Change out to long bails. RU 13 3/8" csg equipment, lay down machine and stabbing board. RIH wi 133/8" csg to 2501'. No problems. Circ csg volume at 5 bpm. No problems. RIH w/13 3/8" csg to 2922'. RIH w/13-3/8" 72#/ft L-80 SL-Boss Casing. Install Tam rotate-to-open port collar @ 990'. (Casing to bottom with slack off FF= 0.45, slack off hookload @ TO = 150M). MU 13-3/8" FMC hanger. PU landing joint and land casing @ 5177', FC @ 5093'. RD LaFluer fillup tool, MU 13-3/8" SL-Boss pin x Buttress XO MU circulating swedge CCM; RD casing equip, C/O bails, reduce pit volume from 868 bbls to 600 bbls RU cement head and hardlines on floor. Hold PJSM. Test lines to 3000 psi. Mix and pump 40 bbls CW 100, 60 bbls Mudpush, drop btm plug, pump 425 bbls of 12.5 ppg lead followed by 105 bbls of 15.8 ppg tail @ 6 bpm. First stage to cover from 5171' to 990' (PC) - based upon caliper, no excess required per AOGCC. drop top plug and displace w/2 bbls cement, 10 bbls wash and 742 bbls of mud. Calcuated strokes to bump = 5416 @ 96% eff; Actual bump @ 5279 strokes 98.5% eff. Final displ pressure = 642 psi, bump plug to 850 psi. Floats 11/18/2001 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ') ) 11/27/2001 11/28/2001 00:00 01:30 00:00 05:30 08:00 10:00 11 :30 01:30 00:00 05:30 08:00 10:00 1:30 3:00 .50 DRILL 22.50 DRILL 5.50 DRILL 2.50 DRILL 2.00 DRILL .50 DRILL .50 DRILL WIPR INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 WIPR INTRM1 DRLG INTRM1 02:30 12:30 13:00 20:00 22:30 12:30 13:00 20:00 22:30 00:00 10.00 DRILL 0.50 DRILL 7.00 DRILL 2.50 DRILL .50 DRILL DRLG DRLG DRLG CIRC WIPR INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 Drlg 12 1/4" hole from 5211' to 5760' Power unit kept dying on Tesco top drive unit. Repair same. Drlg 12 1/4" hole from 5760' to 6063'. Circ 4 bottoms up while roating 120 rpms to clean hole. POH to shoe. Had 20k overpull at 5445'. Remainder of hole in good condition. RIH, Break circ and download Auto-Track Drill from 6063' to 7302' Drld f/7302-7561', survey Circulate btms up 3-1/2+ times, monitor well, pump pill. Poh 17 stand short/wiper trip, no drag or overpull, hole slick. Rih, down link autotrak, break circulation. Drld f17561-7654 Printed: 5/1/2003 3:20:42 PM 11/26/2001 11 :00 11 :30 14:00 17:00 21:00 00:00 - 11 :30 - 14:00 17:00 21:00 00:00 02:30 0.50 DRILL 2.50 DRILL 3.00 DRILL 4.00 DRILL 3.00 DRILL 2.50 DRILL OBSV TRIP PULD PULD TRIP TRIP INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 04:00 08:30 10:30 08:30 10:30 11:00 4.50 CEMENT DSHO SURFAC 2.00 CEMENTCIRC SURFAC 0.50 CEMENT FIT SURFAC 11/25/2001 11/24/2001 11/23/2001 10:00 15:00 17:00 - 15:00 - 17:00 20:00 5.00 CASE NUND SURFAC 2.00 CEMENTTRIP SURFAC 3.00 CEMENTTRIP SURFAC 05:00 06:00 02:00 - 05:00 01 :00 - 03:00 03:00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 04:00 21 :30 - 00:00 20:00 - 00:00 00:00 - 00:30 00:30 - 06:00 06:00 - 09:30 09:30 - 21 :30 06:00 10:00 1.00 CASE 4.00 CASE 3.00 WELCTL OTHR SURFAC 00:00 01:00 2.00 CEMENTOTHR SURFAC 18.50 CEMENTCIRC SURFAC 0.50 CEMENT OTHR SURFAC 1.00 CEMENTOTHR SURFAC 1.00 CEMENTOTHR SURFAC 4.00 CEMENTOTHR SURFAC .00 CEMENTCIRC 2.50 CEMENT CI RC 4.00 CEMENTCIRC SURFAC 0.50 CEMENT OTHR SURFAC 5.50 CEMENT OTHR SURFAC 3.50 CEMENTOTHR SURFAC 2.00 CEMENTOTHR SURFAC NUND SURFAC RURD SURFAC chole manifold valves. Finish testing BOPE to 250-3000 psi. Test switnessed by AOGCC rep John Spalding. RD test equipment. Install wear bushing. Blow down top drive and all lines. NU diverter to check flowline location. Remove some for modification. RU 8" x 10" line from sand trap to WBM pit. Cont' welding on rig floor, #4 shaker stand and pump suction screens. NU flow nipple, drip pan and trip tank lines. RIH wi clean out BHA. RIH to top of firm cement at 5071. Rotate through port collar at 991'. No obstructions. Circ and condition mud for csg test and displacement. Test csg to 3000 psi for 30 min. OK. Circ and condition mud while welding containments on rig floor and pits. Disharge returns to slop tank to empty pill pit. Clean pit and dithces. Mix hi vis pill. transfer OBM from tanks to pits. Blend in brine water. Offload #4 diesel tankers in tank farm. PU and stand back 5 1/2" DP. Pump 60 bbls hi vis pill, 60 bbls H20, 60 bbls base oil and dispaced wi OBM. Take returns to WBM pit. Finish displace well to OBM. Dumped mud to WBM pit until hi vis pill at surface. Switch returns to OBM pit until good mud at surface. Clean shakers and sand trap. Circ at 700 gpm while weighting up system to 9.9+. Used sack barite. RU to PU DP. Replace grabber dies in top drive. PU and std back 51/2" DP. PU, drift and stand back 51/2" DP. Total of approx 15,200' in hole and derrick. Break circ. Drill out FC, cement, FS and 20' new formation to 5211'. Circ 2 bottoms up while rotating to clean hole. Performed 13 ppg FIT wi 540 psi surface press - 9.9 ppg mud @ 3349' TVD. Monitor well. Pump pill. POH. No problems. LD BHA. Vac out HWDP and collars with vac system. MU 12 1/4" bit and Autotrack assembly. RIH w/5 1/2" DP. Shallow test Autotrack at 1000' and 2000' Finish RI H to show. Down link to Autotrack tool. SURFAC SURFAC 11/21/2001 11/22/2001 22:00 - 00:00 00:00 - 02:00 2.00 2.00 WELCTL BOPE SURFAC WELCTL BOPE SURFAC Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 2/6/2001 07:00 09:30 11:00 11 :30 12:00 00:00 09:30 11:00 11:30 12:00 00:00 01:30 2.50 DRILL 1.50 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL .50 DRILL CIRC INTRM1 SURV INTRM1 TRIP INTRM1 SURV INTRM1 DRLG INTRM1 DRLG INTRM1 Printed: Finish p/u drillpipe, stand total of 18 stands dp and stand back. RIH f/shoe filling pipe every 25 stands to 10746'. tight spots(coal) 6159,7904,8743 & 9808' circulate & condition hole for mad pass logging run. orient & run mad pass. RIH, wash last 30' to bottom, no f down link mwd tools. Drld f/10437-11783', ART 9.6 HR Drilled f/11783-11789 ART 1 HR. 5/1/2003 3:20:42 PM 2/5/2001 11 :00 - 12:00 12:00 - 15:00 15:00 - 18:00 18:00 - 20:00 20:00 - 00:00 00:00 - 01 :30 01 :30 - 07:00 .00 DRILL 3.00 DRILL 3.00 DRILL 2.00 DRILL 4.00 DRILL 1.50 DRILL 5.50 DRILL CIRC INTRM1 TRIP INTRM1 OTHR INTRM1 OBSV INTRM1 TRIP INTRM1 PULD INTRM1 TRIP INTRM1 12/4/2001 2/3/2001 2/2/2001 12/1/2001 11/30/2001 11/29/2001 03:00 04:00 05:30 08:00 00:00 - 03:00 22:30 23:00 00:00 15:00 15:30 00:00 01:30 02:30 03:00 06:00 15:30 16:30 18:00 19:30 13:00 - 14:00 14:00 - 00:00 00:00 - 05:30 05:30 - 07:00 07:00 - 19:00 19:00 - 20:00 20:00 - 00:00 00:00 - 09:00 09:00 - 12:30 12:30 - 14:30 14:30 - 15:30 15:30 - 00:00 00:00 - 16:00 16:00 - 17:00 17:00 - 20:30 20:30 - 22:30 .00 RIGMNT RSRV INTRM1 0.00 DRILL DRLG INTRM1 5.50 DRILL DRLG INTRM1 1.50 DRILL CIRC INTRM1 2.00 DRILL DRLG INTRM1 1.00 DRILL CIRC INTRM1 4.00 DRILL DRLG INTRM1 9.00 DRILL DRLG INTRM1 3.50 DRILL CIRC INTRM1 2.00 DRILL WIPR INTRM1 1.00 DRILL CIRC INTRM1 8.50 DRILL DRLG INTRM1 6.00 DRILL DRLG INTRM1 1.00 DRILL REAM INTRM1 3.50 DRILL DRLG INTRM1 2.00 DRILL CIRC INTRM1 Service top drive unit. Drld ffi654-8217' Drld f/8217-8313' Circulate to clean hole. Drld f/8313-9057' Circulate to clean hole. circulating based on torque and drag - 700' Drld f/9057-9187' Drilling f/9187-9523', reaming each stand on connection. circulate 3+ bottoms up, pump dry job. wiper trip to 8594', little drag, one knot @ -8800', rih, 2' fill on bottom. circulate one bottoms up. drilled f/9523-9743', 5.6 hr rotating. Drilled f/9743-10465, ART 12.85 HR BACK REAM STAND 109 DUE TO HIGH P/U WEIGHT. Drld f/10465-10652', ART 2.7 HR CIRCULATE HOLE CLEAN, WORK PIPE @ 170 RPM TWO BTMS UP. Downlink Autotrak. Drld f/1 0652-1 0685', ART ..45 hr Drilled f/1 0685-11168, ART 9.3 HRS. Repair electrical f/driller to top drive, circulated while repairing. Drilled f/11168-11340', ART 5.6 HR Drill from 11340' to 11408' Lost pulse on auto-track tool Drill from 11408' to 11438' Circ and work on Auto-track and pump pill POOH to BHA Change handling equipment to 5" Laydown Autotrak and stabilizer UD Iron Roughneck for repairs R/U and begin testing BOPE-AOGCC representatives John Crisp and Jeff Jones waived witnessing test. Test choke manual, floor valve, dart valve, HCR,250/3000, test bop's and test koomey-all good. Rig down test equipment, pull test plug & set wear ring. P/U iron roughneck, set on track, plumb hydraulic lines. P/U autotrak & M/U, map sub, stop sub, program mwd, clean rig floor M/U float sub, stab, 2 stands DC, RIH w/drill pipe to shoe, circulate 20 stds in to check autortrak mwd tools. pump slow thick mud, test mwd. RIH to shoe # 5177'. Hang blocks, cut & slip drilling line, set up drawworks brakes. TESCO mechanic service engine on hydraulic power pack. P/U 5-1/2 DP & rack back in derrick @ 04:00 05:30 08:00 11 :00 23:00 00:00 15:00 15:30 00:00 01:30 02:30 03:00 06:00 15:30 16:30 18:00 19:30 00:00 .00 DRILL .50 DRILL 2.50 DRILL 3.00 DRILL 3.00 DRILL 0.50 DRILL 1.00 DRILL 5.00 DRILL 0.50 DRILL 8.50 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 9.50 DRILL 1.00 DRILL 1.50 DRILL 1.50 DRILL 4.50 DRILL OTHR INTRM1 OTHR INTRM1 PULD INTRM1 PULD INTRM1 SURV INTRM1 DRLG INTRM1 DRLG INTRM1 OTHR INTRM1 DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 CIRC INTRM1 TRIP INTRM1 PULD INTRM1 PULD INTRM1 TRIP INTRM1 OTHR INTRM1 OTHR INTRM1 11/28/2001 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: l ) ) 2/14/2001 2/15/2001 04:00 23:00 - 00:00 00:00 - 00:00 00:00 - 04:00 04:30 0.50 DRILL .00 DRILL 24.00 DRILL 4.00 DRILL DRLG DRLG DRLG DRLG NTRM1 INTRM1 INTRM1 INTRM1 7:30 - 22:00 22:00 - 23:00 23:30 00:00 02:30 03:00 09:00 2/13/2001 14:00 - 22:30 22:30 - 23:30 3:00 14:00 00:00 02:30 03:00 09:00 17:30 4.50 DRILL .00 DRILL 0.50 DRILL 2.50 DRILL 0.50 DRILL 6.00 DRILL 8.50 DRILL 8.50 DRILL .00 DRI LL .00 DRILL DRLG OTHR DRLG DRLG DRLG DRLG DRLG DRLG DRLG DRLG NTRM1 NTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 NTRM1 Drlg ,2 1/4" hole from 15,348' to 15,354' Drilling 12 1/4· hole from 15354' to 15706' Drilling 121/4" hole from 15706' to 15722' tuff. Pop off on pump released. Low pressure valve failed in pop off line. Bull plug outlet. Check line for additional low pressure fittings. None located. Drlg 12 1/4" hole from 14116' to 14664'. ADT - 18.9 hrs Drlg 12 1/4" hole from 14664' to 14877'. No top drive problems. Changed out several valve cap seals on mud pumps. Shut down #1 pump to change swab. #3 pump would not assign. Trouble shoot SCR system. Drlg 12 1/4" hole from 14877' to 15034'. Change liner and swab in #2 mud pump. #3 pump down for a swab. Circ with #1 pump. Drlg 12 1/4" hole from 15034' to 15040'. Drlg 12 1/4" hole from 15,040' to 15,069'. Low fuel line pressure to the Tesco unit. Drlg 12 1/4" hole from 15,069' to 15,257'. Top half fo the Oteco pop-off valve seperated on #1 pump. Set back one stand. Circ at 5 bpm. Clean OBM from buildings and pad. Check torque on #2 and #3 pop-off valves. OK. Increase flow rate to 900 gpm while replaceing #1 pop-off. Autotrack sleeve rotation indicated hole washout. Pull 2 stds. Circ at low rate until #1 pump ready to go. Check all suctions screens. Drlg 12 1/4" hole from 15,257' to 15,348'. Saversub damaged due to grabber position. Pull one stand. saversub. Printed: 5/1/2003 3:20:42 PM No problems. Formation - Dense volcanic Changeout 12/11/2001 12/12/2001 2/9/2001 2/1 0/2001 00:00 00:00 00:00 01:00 01:30 20:00 22:30 00:00 00:00 00:00 13:00 01:00 01:30 20:00 22:30 00:00 00:00 00:00 24.00 DRILL 13.00 DRILL .00 DRILL 0.50 DRILL 8.50 DRILL 2.50 DRILL 1.50 DRILL 24.00 DRILL 24.00 DRILL DRLG DRLG DRLG CrRC DRLG CIRC DRLG DRLG DRLG INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 drive problems. Drilled f/12627-12651, ADT 1 HR. Circulate & work pipe, restart tesco top drive unit. Drilled f/12651-13057, ADT 12.5 HR. Circulate & work pipe, SCR pump problems, Drilled f/13057-13095', ADT 1.3 HR. Drilled f/13095-1371 0', ADT 19.3 HR Drilled f/13710-14116', ADT 19.8 HRS, 18-20 k drilling repair tesco unit. f/ 14000' on @ 30 rpm, 12/8/2001 10:30 11:30 12:00 11:30 12:00 00:00 .00 DRILL 0.50 DRILL 12.00 DRILL CIRC CIRC DRLG INTRM1 INTRM1 INTRM1 12/7/2001 00:00 04:00 05:00 05:30 06:00 03:00 - 00:00 04:00 05:00 05:30 06:00 10:30 4.00 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 4.50 DRILL 21.00 DRILL DRLG INTRM1 CIRC INTRM1 OTHR INTRM1 DRLG INTRM1 OTHR INTRM1 DRLG INTRM1 Hydraulic leak on top drive (in containment) poh and stand back one stand, circulate while fixing hydraulic hose in motor complex, down link auto trak. Drilled f/11789-12231', ART 12.6 HR. TESCO motor shut down 3 times after hydraulic leak, no downtime other than restart. Drilled f/12231-12388' ADT 3.75 HR. Circulated & worked pipe, restarted TESCO unit 5 times. Work drillpipe, work on #3 mud pump, #2 mud pump down also. Drilled f/12388-12414' ADT .75 HR. Washout in nipple to pressure guage in stand pipe in cellar, Work pipe, clean cellar, weld new nipple in standpipe. Circulating cold mud & working pipe. Restart TESCO unit Rotating and circulating to clean cuttings from hole. Drilled f/12414-12627' ADT 7.4 HR. NEARING torque limits, alternating one stand in low gear wlone stand in high gear, improved penetration while drilling in low and clean hole in high gear. Increased circulating time after drilling stand in low gear. See pwd log f/detailed pump & top 2/6/2001 01 :30 - 03:00 .50 DRILL OTHR NTRM1 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group ) ') 12/22/2001 2/21/2001 0:30 00:00 - 04:30 04:30 - 07:30 07:30 - 10:30 00:00 - 00:00 2:00 - 00:00 7:00 6.50 DRILL 4.50 DRILL 3.00 DRILL 3.00 DRILL 24.00 DRILL 12.00 DRILL CIRC DRLG INTRM1 CIRC INTRM1 WIPR INTRM1 NTRM1 INTRM1 DRLG DRLG NTRM1 2/19/2001 2/20/2001 12/18/2001 Finish RU test equipment. Pull wear bushing. Set test plug. Test all BOPE to 250-3000 psi. No failures. Witness of test was waived by AOGCC rep. John Crisp. RD test equipment. Install weaar bushing. MU new BHA. Program Autotrack tool. Change out jars. Change elevaator inserts. RIH to 2500'. Test Aouttrack. OK. RIH to shoe. CBU. Service rig and top drive. Inspect brake bands. RIH to 12,265'. Fill pipe and circ at 7287',9623' and 11,976'. No hole problems. Finish RIH to 15,355'. Fill pipe and circ at 14,321'. Minor tight spots at 14,015',14,135' and 14,902'. No problems. Precautionary ream from 15,355' to 15,448'. Developed a top drive hydraulic problem while making a connection. Circ and reciprocate pipe while troubleshooting top drive problem. Replace hydraulic motor on top drive. Function test top drive. Troubleshoot short in wiring assembly. Ream from 15,448' to 15,810'. No problems. Drilling 12 1/4" hole from 15,810' to 15,895'. Drlg 12 1/4" hole from 15895' to 16011'. No problems. Service rig. Swivel, blocks, crown and drawworks. Drlg 12 1/4" hole from 16011' to 16255'. No problems. Drilling 12 1/4" hole from 16255' to 16337'. No problems Swivel packing leaking. Std back one std. Work pipe periodically while replace and test swivel packing. Take survey. Down link to autotrack. Make connection. Drilling 12 1/4" hole from 16337' to 16355'. No problems ADT - 0000 to 1200........4.4 hrs Drilling 12 1/4" hole from 16355' to 16504'. No problems ADT -1200 to 0000........10.1 hrs Drilling 12 1/4" hole from 16504' to 16789. No problems ADT - 21.3 hrs Drilling 12 1/4" hole from 16789' to 16826'. ADT- 4.0 hrs. Circ 2 bottoms up while rotate and reciprocate pipe. Monitor well. POH w/2 stds DP. Pump dry-job. POH wI total of 15 std DP. RIH to TO. No problems. Circ 4 bottoms up to condition mud and clean hole for csg. Rotate pipe at 120 rpms while reciprocating DP. Pump dry-job. Printed: 5/1/2003 3:20:42 PM 0:00 11:00 2:00 6:30 00:00 09:00 09:30 00:00 06:00 04:00 00:00 - 03:00 05:00 - 06:00 06:00 - 10:30 10:30 - 13:00 13:00 - 16:00 16:00 - 16:30 6:30 - 17:30 7:30 - 00:00 11:00 12:00 16:30 00:00 09:00 09:30 00:00 06:00 0:00 2:00 03:00 - 04:00 .00 DRILL .00 DRILL 4.50 DRILL 7.50 DRILL 9.00 DRILL 0.50 DRILL 14.50 DRILL 6.00 DRILL 4.00 DRILL .00 DRILL 3.00 DRILL .00 WELCTL OTHR INTRM1 4.50 DRILL PULD INTRM1 2.50 DRILL TRIP INTRM1 3.00 DRILL TRIP INTRM1 0.50 DRILL CIRC INTRM1 1.00 DRILL OTHR INTRM1 6.50 DRILL TRIP INTRM1 8.00 DRILL DRLG DRLG REAM INTRM1 DRLG INTRM1 DRLG INTRM1 OTHR INTRM1 DRLG INTRM1 DRLG INTRM1 DRLG INTRM1 TRIP REAM REAM INTRM1 NTRM1 INTRM1 NTRM1 NTRM1 12/17/2001 18:00 22:30 00:00 01:30 04:30 06:00 06:30 01 :00 - 04:30 22:30 00:00 01:30 05:00 06:00 06:30 18:00 4.50 1.50 1.50 3.50 .50 DRILL 0.50 DRILL 11.50 DRILL 3.50 DRILL DRILL PULD INTRM1 WELCTL OTHR INTRM1 WELCTL OTHR INTRM1 WELCTL BOPE INTRM1 TRIP INTRM1 OBSV INTRM1 TRIP INTRM1 CIRC NTRM1 drive. Drrilling 12 1/4" hole from 15725' to 15810' Drilling at 15810'. Angle dropping at the bit. 0 penetrartion rate. Pressure increase with bit on bottom. Circ 2 bottoms up at 920 gpm. Rotate pipe at 130 rpms while recipracate a full stand. POH slow with 5 stds wet. No problems. Monitor well. Pump dry job. POH. Monitor well at shoe. OK. Minor tight spots at 13,003', 12,995' and 12,500'. Suspect filter cake build up on sand intervals. Break bit. Download autotrack tool. LD lower BHA. RU :0 test BOPE. 12/16/2001 05:30 - 00:00 00:00 - 01 :00 18.50 DRILL .00 DRILL DRLG DRLG INTRM1 INTRM1 12/15/2001 04:30 - 05:00 05:00 - 05:30 0.50 DRILL 0.50 DRILL DRLG DRLG INTRM1 INTRM1 Drilling 12 1/4" hole from 15722' to 15725', Grabber malfunction on top drive. Suspect electrical connection on top Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 0:00 11:00 11:30 2:00 6:00 11 :00 11 :30 12:00 16:00 22:00 .00 0.50 0.50 4.00 6.00 WELCTL EaRP PROD WELCTL EaRP PROD DRILL PULD PROD DRILL OTHR PROD DRILL PULD PROD Printed: ring. Blowdown topdrive and clear floor. UD test joint UD stabbing board RlU tongs to breakdown topdrive Breakdown connections in topdrive and inspect.-OK M/U BHA. M/U Pathfinder stabilizer and upload. Peform pump test 500 gpm-OK 5/1/2003 3:20:42 PM @ 2/27/2001 06:30 08:30 23:00 00:00 05:00 08:00 15:00 15:30 18:00 00:00 00:30 01:00 12/26/2001 12/25/2001 2/24/2001 6:30 - 20:30 00:00 06:30 3:30 12/23/2001 POH to 13000'. Minor tight hole at 15112' 13740'. No problems. Finish POH. SLM. No corrections. No problems. LD BHA. Download MWD. LD autotrack. Pull wear bushing. Set test plug. Change top pipe rams to 9 5/8" door seals to 3000 psi. OK. RU to run csg. CHange out bales. RU fill up tool, spider, elevators, tongs and lay down machine. Adjjust stabbing board. PJSM on running csg. The stabber two-blocked the stabbing board and bent the stops on the board. Remove stabbing board and repair same. Hang stabbing board, rig up to run casing & hold PJSM f/running casing with rig crews, weatherford csg. RIH w/9-5/8" casing, elevators freezing up w/ice in slip dies, steaming elevators and casing thread, change liners in mud pumps 1 & 2 while running casing Circulate bottoms up at 13-318" casing shoe. Continue rih w/9-5/8" casing. Circulate bottoms up @ 8000'. up weight 230k, down 135k. Continue rih wlcsg, filling every joint. Continue running 9-5/8" casing. Circulate Btms Up, 7400 stks. Continue rih wlcsg, plu roller centralizers @ 11575', tag btm @ 16839', plu install hanger, shoe @ 16825', ran total of 147 jts 47# & 215 jts 53.5# 1-80 boss casing. No tight spots, casing to bottom wino problems. Rig up surface lines & Dowell for cementing and circulating. Circulate and reciprocate casing while rigging down weatherford casing equipment and lay down machine. CBU Safety meeting wI crews and cementers Mix and pump 40 bbl CW100, dropped plug, 60 bbl Mud push @ 12 ppg, 43 bbl Lead @ 12.5 ppg, dropped 2nd plug, 98 bbl Tail @ 15.8 ppg. Dropped top plug. Displace cement wi 1082 bbl. mud using rig pumps. Plug did not bump WOC until cement set Change lower pipe rams from 9-5/8" to 5-1/2" Fish topdrive bolts out of stack Remove cement head, Backout landing jt. and UD. RID elevators and bales. RlU topdrive bales and elevators. P/U jt of 5-1/2" and M/U pack-off setting tool. Set pack-off and test to 5000 psi for 10 min.-OK. RID setting tool Prep to test BOPE Fill stack and choke manifold. Test BOPE to 250/3000 psi. Top drive IBOP failed. Replace top drive IBOP Pull test plug. Set wear ring. RID test equip. Run in 2 LOS for 08:30 0:00 00:00 06:30 08:00 15:00 15:30 18:00 23:00 00:30 01:00 05:00 2.00 .50 3.00 CEMENT DISP INTRM1 7.00 CEMENTOTHR INTRM1 0.50 DRILL PULD PROD 2.50 DRILL PULD PROD 5.00 DRILL PULD PROD 0.50 CEMENTCIRC INTRM1 0.50 CEMENT SFTY INTRM1 4.00 CEMENT PUMP INTRM1 .00 6.50 WELCTL EaRP PROD WELCTL EaRP PROD DRILL PULD PROD WELCTL BOPE PROD wear 20:30 21:00 5:30 16:30 22:00 23:00 00:00 09:30 11:00 01:00 00:00 20:30 21:00 21:00 00:00 6:30 22:00 23:00 00:00 09:30 11:00 20:30 01:00 21:00 00:00 5:30 0.50 CASE 3.00 CASE .00 CASE 5.50 CASE 1.00 CASE 1.00 CASE 9.50 CASE 1.50 CASE 9.50 CASE 14.50 CASE .00 CASE 0.50 CASE 3.00 CASE CIRC CIRC CIRC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 RUNC INTRM1 CIRC INTRM1 RUNC INTRM1 SFTY SFTY INTRM1 RUNC INTRM1 RUNC INTRM1 NTRM1 NTRM1 NTRM1 06:30 13:30 6:30 4.00 CASE 6.50 DRILL TRIP 7.00 DRILL PULD 3.00 WELCTL EaRP RURD INTRM1 INTRM1 INTRM1 INTRM1 Test 12/22/2001 17:00 - 00:00 7.00 DRILL TRIP NTRM1 14930' 14824' 14610'and Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) r~ ) 1/5/2002 1/4/2002 08:30 15:00 17:00 19:00 23:00 00:00 01:30 03:00 04:30 00:00 0:30 15:00 17:00 19:00 23:00 00:00 01:30 03:00 04:30 00:00 10:30 11:30 6.50 DRILL TRIP PROD 2.00 RIGMNT RSRV PROD 2.00 DRILL PULD PROD 4.00 DRILL TRIP PROD 1.00 DRILL CIRC PROD 1.50 DRILL CIRC PROD 1.50 DRILL TRIP PROD 1.50 DRILL SURV PROD 9.50 DRILL DRLG PROD 0.50 DRILL DRLG PROD .00 DRILL SURV PROD 1/3/2002 9:00 - 20:00 20:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 02:30 02:30 - 05:00 05:00 - 06:30 06:30 - 08:30 00:00 03:00 03:30 15:00 1/2/2002 1/1/2002 03:00 03:30 15:00 9:00 1.00 WELCTL BOPE PROD 4.00 WELCTL BOPE PROD 1.00 WELCTL BOPE PROD 1.00 WELCTL OTHR PROD 0.50 RIGMNT RSRV PROD 2.50 DRILL PULD PROD 1.50 DRILL PULD PROD 2.00 DRILL DEOT PROD 3.00 DRILL 0.50 DRILL 11.50 DRILL 4.00 DRILL 02:30 00:00 22:30 00:00 22:30 00:00 21.50 DRILL 22.50 DRILL .50 DRILL DRLG DRLG CIRC PROD PROD PROD up. Drilled f/17371-17798', ART 18.4 HR. Drilled f/17798-18191', ART 19.5 HR Circulate and reciprocate dp cleaning up hole prior to POH f/bit. Stand back one stand every hour while circulating. Circulate to POH (total 3 circulations). Monitor well, pump pill. POH to 300', no drag in open hole. Monitor well, POH w/bha, pump baseoil thru bha, download nukes, download mwd. Pathfinder stabilizer blades worn down -50/1000's, bit cone centers gone, cone bearings loose. Pull wear ring, rig up and set test plug. Test bope, annular 300/2000, rams 300/3000 psi-ok. Finish testing bope. Note AOGCC witnessing waived by Winton Obert. Pull test plug, set wear ring, UD test jt. Service top drive, change saver sub & grabber dies. UD Iwd's & mwd, P/U same, M/U new 8-1/2" bit. Program & upload BHI MWD tools, PJSM & load w/nukes. RI H w bha, test w/mud pump bhi and pathfinder, pathfinder changed out transduceer & chart recorder. RIH slm, fill dp every 5000' w/mud, circulate every fillup. Slip & cut 116' drilling line. Pick up 21 singles and stand back in derrick. RIH, f/9650-16718', slm. Fill pipe, circulate and condition mud, bottoms up. Finish circulating bottoms up @ csg shoe, monitor well. RIH, slm f/16716-18032'. Mad pass & precautionary ream f/18032-18191'. Drilled f/18191-18470', ART 15.7 hrs. Drilled f/18470-18630, ART 8.5 HR. Surved w/mwd, circulate 1/2 hr, set stand back in derrick. Printed: 5/1/2003 3:20:42 PM CIRC OBSV TRIP PULD PROD PROD PROD PROD stab failed, M/U BHI MWD/LWD and test Testing MWD (load test) program tool, P/U BHA. P/U jt dp, test LWD, rih P/U 54 jts drillpipe, f cement @ 16653'. Circulate and condition mud for casing test. Circulate and condition mud. Test casing to 3000 ps pressure bled oft slowly. lub rig, clean floor, circulate mud to eliminate air entrainment. Test csg to 3000 psi, good test. RIH to tag float collar, drill out clr @ 16727' drillers depth, drill through cement stringer to shoe, hard cmt 50' above shoe, drld shoe @ 16822' drill out to 16824', new formation to 16828', circulate hole clean f/FIT. F.\.T. to 12.8 ppg emw, wanted fit prior to drilling further due to fear of upcoming coal seam. Drilled f/16828-16846' (20'+ new hole). ART 1 HR Circulate hole clean for FIT test. Thin coal section -6". Perform F.\.T. to 12.8 ppg emw. Drilled f/16846-16965' ART 9.61 HR. Drill from 16965' to 17315'-ADT =19.1 hrs Drilled f/17315-17371, ART 2.0 HR Back ream full 90' stand to clean hole on connection check out 12/30/2001 12/31/2001 11 :00 12:00 13:30 14:00 00:00 00:00 02:00 2:00 13:30 14:00 00:00 00:00 02:00 02:30 .00 DRILL .50 DRILL 0.50 DRILL 10.00 DRILL 24.00 DRILL 2.00 DRILL 0.50 DRILL DRLG PROD CIRC PROD FIT PROD DRLG PROD DRLG PROD DRLG PROD REAM PROD bottoms 0:00 9:30 00:00 02:00 02:30 04:00 05:00 11:00 00:00 02:00 02:30 04:00 05:00 - 10:00 .00 DRILL 4.50 DRILL 2.00 DRILL 0.50 DRILL 1.50 DRILL 1.00 DRILL 5.00 DRILL FIT CIRC CIRC OTHR CIRC OTHR DRLG PROD PROD PROD PROD PROD PROD PROD 12/29/2001 22:00 00:00 03:30 05:00 00:00 03:30 05:00 19:30 2.00 DRILL 3.50 DRILL 1.50 DRILL 14.50 DRILL PULD PROD DEOT PROD PULD PROD TRIP PROD drillpipe every 4000' tag 12/27/2001 12/2812001 load w/nukes. Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) ) Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 1/5/2002 11 :30 - 16:30 5.00 DRILL CIRC PROD 16:30 - 18:30 2.00 DRILL OBSV PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 1/6/2002 00:00 - 04:30 4.50 DRILL TRIP PROD 04:30 - 05:00 0.50 DRILL OTHR PROD 05:00 - 09:00 4.00 DRILL PULD PROD 09:00 - 09:30 0.50 DRILL OTHR PROD 09:30 - 12:00 2.50 DRILL PULD PROD 12:00 - 16:00 4.00 DRILL TRIP PROD 16:00 - 21 :30 5.50 DRILL TRIP PROD 21 :30 - 00:00 2.50 DRILL TRIP PROD 1/7/2002 00:00 - 08:00 8.00 LOG DLOG PROD 08:00 - 09:00 1.00 LOG CIRC PROD 09:00 - 10:00 1.00 LOG RURD PROD 10:00 - 10:30 0.50 LOG RURD PROD 10:30 - 14:00 3.50 LOG CIRC PROD 14:00 - 15:00 1.00 LOG OTHR PROD 15:00 - 18:00 3.00 LOG DLOG PROD 18:00 - 20:00 2.00 LOG OTHR PROD 20:00 - 22:30 2.50 LOG DLOG PROD 22:30 - 00:00 1.50 LOG DLOG PROD 1/8/2002 00:00 - 07:00 7.00 LOG DLOG PROD 07:00 - 07:30 0.50 LOG DLOG PROD 07:30 - 08:00 0.50 LOG DLOG PROD 08:00 - 09:30 1.50 LOG DLOG PROD 09:30 - 10:00 0.50 LOG OTHR PROD 10:00 - 10:30 0.50 LOG DLOG PROD 10:30 - 11 :30 1.00 LOG DLOG PROD 11 :30 - 12:30 1.00 LOG DLOG PROD 12:30 - 23:00 10.50 LOG DLOG PROD 23:00 - 00:00 1.00 LOG DLOG PROD 1/9/2002 00:00 - 01 :30 1.50 LOG DLOG PROD 01 :30 - 02:00 0.50 RIGMNT RSRV PROD 02:00 - 02:30 0.50 LOG OTHR PROD 02:30 - 13:30 11.00 LOG DLOG PROD 13:30 - 16:30 3.00 LOG PULD PROD 16:30 - 18:00 1.50 DRILL PULD PROD 18:00 - 00:00 6.00 DRILL TRIP PROD 1/10/2002 00:00 - 04:30 4.50 DRILL TRIP PROD 04:30 - 05:00 0.50 DRILL CIRC PROD 05:00 - 06:00 1.00 DRILL TRIP PROD 06:00 - 06:30 0.50 DRILL REAM PROD 06:30 - 10:30 4.00 DRILL CIRC PROD 10:30 - 13:00 2.50 DRILL TRIP PROD 13:00 - 15:00 2.00 RIGMNT OTHR PROD 15:00 5:30 0.50 RIGMNT RSRV PROD Printed: Circulate bottoms up 4+ times, work pipe and stand back every hour. Monitor well, drop 2.75" rabbit, pump pill, poh to shoe @ 16825' Monitor well, POH for dp conveyed logs f/16825-8260'. Finish POH to bha. Flush out bha wlbase oil, clo 5-1/2 elevators to 5". POH wlbha, down load mwd & lay down drilling assy." Clear & clean rig floor of excess tools & equipment, clo elevator inserts to 5". PJSM, wlrig crew & schlum, rlu schlum to run dp conveyed logs. RIH f/84-3000', circulate one bottoms up. RIH to 9300', circulated bottoms up to condition mud. PJSM, RIH to 107', rabbit 11 stands not previously rabbited on trip out. Continue to RIH wldp conveyed logging tools f/10700-16756', fill drillpipe @12378' & 15470'. Circulate pipe volume. PJSM, R/U Schlumberger equipment & wire. Install side entry sub, xo's & wire connection. Run cable in hole f/latch-up, pump wireline down to latch up. Clamp wireline @ side entry sub. RIH wldp logging tools. Repair drawworks, broken low clutch chain. RIH wldp logging tools. Log out w/CMR f/18540-18250' Finish running CMR log up to 16,886'. RIH with DP to 17,169'. Log repeat pass from 17,169' to 17,073'. RIH wi DP to 18,013'. Change top drive grabbers. Install 2 safety keepers on high drum clutch chain. Co nt' RIH with DP to 18,540'. Run MDT log. Schlumberger generator went down. Troubleshoot and change out generators. Finish MDT log. Total of 30 settings from 18,447' to 17,035'. POH to shoe. Release side entry clamp and and pull WL free of logging tools. POH wI WL. Sclumberger finished POH with WL. RD side entry sub and WL equipment. Service rig. Monitor well. Pump dry-job. POH wi 51/2" DP. No problems. PJSM. LD Schlumberger logging tools. Clear floor. MU BHA #16. RIH wi 51/2" DP. RIH to 16804'. Circ 30 min to thin mud. Evaluate electrical load while running 2 pumps with drawworks in hihg gear. No problems. RIH to 18557'. No problems. Precautionary ream from 18557' to 18630'. No problems. Circ hole clean and condition mud. POH to shoe. 23k over at 18353'. No problems. Cut and slip driJling line. Service rig. 5/1/2003 3:20:42 PM Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 08:30 09:00 11:00 14:00 14:30 15:30 09:00 11 :00 14:00 - 14:30 15:30 00:00 0.50 CEMENT RURD PROD 2.00 CEMENT TRIP PROD 3.00 CEMENT PULD PROD 0.50 LOG SFTY PROD 1.00 LOG RURD PROD 8.50 LOG ELOG PROD 1 115/2002 14:00 19:00 21:00 21:30 00:00 9:00 21:00 21:30 00:00 08:30 5.00 2.00 0.50 2.50 8.50 CEMENTCIRC PROD WAlTON ORDR PROD CEMENTOTHR PROD CEMENTTRIP PROD CEMENT TRIP PROD 1/14/2002 19:30 22:30 23:00 00:00 11:00 11:30 2:00 14:30 18:00 18:30 1/13/2002 1/12/2002 22:30 23:00 00:00 11 :00 11 :30 2:00 4:00 8:00 8:30 9:30 21:00 00:00 06:30 07:00 09:00 15:30 00:00 01:30 03:30 05:30 11:00 14:00 00:00 05:00 07:00 09:00 10:00 12:00 12:30 3.00 CEMENT TRIP PROD 0.50 CEMENT PULD PROD 1.00 CEMENTTRIP PROD 11.00 CEMENTTRIP PROD 0.50 CEMENTCIRC PROD 0.50 CASE DEQT PROD 2.00 CEMENT DSHO PROD 3.50 CEMENT TRIP PROD 0.50 CEMENT RURD PROD 1.00 CEMENTTRIP PROD 17:00 14:30 00:00 06:30 07:00 09:00 14:30 21:00 00:00 01:30 03:30 05:30 11:00 14:00 00:00 05:00 07:00 09:00 10:00 12:00 12:30 14:30 7:00 3.00 CEMENTTRIP PROD 6.50 CEMENTTRIP PROD 0.50 CEMENTOTHR PROD 2.00 WELCTL OTHR PROD 5.50 WELCTL BOPE PROD 4.00 CEMENTOTHR 8.50 DRILL TRIP PROD 1.50 DRILL TRIP PROD 2.00 DRILL PULD PROD 2.00 CASE RURD PROD 5.50 CASE PULR PROD 3.00 CASE PULR PROD 10.00 CASE RUNL PROD 5.00 CASE RUNL PROD 2.00 CASE RURD PROD 2.00 CASE RUNL PROD 1.00 CASE RURD PROD 2.00 CASE CIRC PROD 0.50 CASE SFTY PROD 2.00 CEMENT PUMP PROD 2.50 CEMENT DISP PROD PROD POH. No problems Finish POH. LD BHA. Clear floor. RU Weatherford csg equipment and lay down machine. PJSM. RIH wi 48 jts 7" 26# L-80 SL-HT csg. MU Baker liner hanger and pkr assembly. Break circulation. RIH wi liner on 51/2" DP to 12000'. Fill pipe every 20 stds. Continue RIH wI 7" liner to 16735'. MU TDH and pups. Hang back in derrick. Circ for 15 mins. RI H wi 7" liner to 18625'. RU TDH and cement hose. Circ and condition mud. PJSM with all personel. Test lines to 4000 psi. Pump 40 bbls CW 101,60 bbls Mudpush XLO, 92.5 bbls 11.0 ppg LiteCRETE, drop dart and kick out with 10 bbls H20. Rig displaced wi 420 bbls OBM. Bumped plug. Set liner hanger. PU and set liner top pkr. Wash out tie back sleeve. Circ out flush, cement and cement contaminated mud. POH wi 5.5" DP. POH wi 5.5" DP. LD Baker liner running tool. Clean OBM from rig floor. Clear floor. Pull wear bushing. RU BOP test equipment. Test BOPE to 250-3000 psi wi annular to 2500 psi. Test witnessed by AOGCC rep Lou Gramaldi. MU BHA RU Weatherford to run 3.5" tbg. Investigate improper stenciling on 3.5" tbg. Some pipe marked as 15.50 and some marked N-80. Verified with Weatherford that all pipe on location was 12.95# P-110. Confirmed by 2 grooves on P-110 boxes and calipering pipe marked as 15.5#. PU, rabbit and RIH wi 61 jts 3.5" 12.95# P-11 0 PH-6 tbg. MU 9.625 csg scraper in string. RIH with 5.5" DP. RIH wi 5.5" DP and 3.5 tbg to 18473'. Circ hole. Test csg and liner lap to 3500 psi for 30 min. Drill out cement to landing collar at 18499'. Drill out landing collar and green cement to 18536'. Circ hole clean. Waiting on orders. Mix and pump dry job. POH. POH wi 51/2" DP to 9 5/8" csg scraper. Monitor well before change over to 3 1/2" equipment. RU Weatherford's 3 1/2" tbg equipment. POH wet wi 20 stds 3 1/2" tbg. POH. LD BHA. Clear and clean floor. PJSM on wireline operations. RU Schlumberger and MU tools. RIH wi USIT log on wireline. Approx 14700' at midnight running at 1000 ft/h r. Printed: 5/1/2003 3:20:42 PM 1/10/2002 1/11/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 1/22/2002 15:00 18:00 18:30 00:00 00:30 01:00 18:00 18:30 00:00 00:30 01:00 07:00 3.00 FRMTST RURD PROD 0.50 FRMTST SFTY PROD 5.50 FRMTST SEaT PROD 0.50 FRMTST RURD PCPTST 0.50 FRMTST SEaT PCPTST 6.00 FRMTST OTHR PCPTST 1/21 12002 1/20/2002 1/19/2002 1/18/2002 1/17/2002 2:30 4:00 21:00 00:00 03:00 03:30 05:00 09:30 00:00 - 09:30 23:00 - 00:00 00:00 - 01 :30 01 :30 - 00:00 20:30 - 23:00 00:00 05:30 12:00 13:30 14:00 14:30 16:00 23:00 23:30 00:00 00:30 01:30 02:00 05:00 08:00 08:30 09:00' 00:00 04:00 05:00 08:30 09:30 11 :00 6:00 6:30 5:00 16:30 20:30 6:00 05:30 12:00 13:30 14:00 14:30 16:00 23:00 23:30 00:00 00:30 01:30 02:00 05:00 08:00 08:30 09:00 00:00 04:00 05:00 08:30 09:30 11:00 15:00 14:00 21:00 00:00 03:00 03:30 05:00 15:00 2:30 1.50 FRMTST OTHR PROD 7.00 FRMTST RURD PROD 3.00 FRMTST RURD PROD 3.00 FRMTST SEaT PROD 0.50 FRMTST SFTY PROD 1.50 FRMTST RURD PROD 10.00 FRMTST OTHR PROD .00 FRMTST RURD PROD .50 FRMTST PULD PROD 22.50 FRMTST TRIP PROD 5.50 LOG ELOG PROD 6.50 LOG ELOG PROD 1.50 LOG ELOG PROD 0.50 LOG RURD PROD 0.50 FRMTST OTHR PROD 1.50 FRMTST TRI P PROD 7.00 FRMTST TRI P PROD 0.50 FRMTST SFTY PROD 0.50 CASE DEaT PROD 0.50 CASE DEaT PROD 1.00 FRMTST CIRC PROD 0.50 FRMTST CIRC PROD 3.00 FRMTST CIRC PROD 3.00 FRMTST OTHR PROD 0.50 FRMTST CI RC PROD 0.50 FRMTST SFTY PROD 15.00 FRMTST TRIP PROD 4.00 FRMTST TRI P PROD 1.00 FRMTST TRIP PROD 3.50 FRMTST TRIP PROD 1.00 FRMTST RURD PROD 1.50 FRMTST TRIP PROD 4.00 WELCTL EaRP PROD 0.50 FRMTST SFTY 4.00 FRMTST PULD 2.50 FRMTST PULD 3.00 CASE 9.50 FRMTST TRIP .00 WELCTL BOPE PROD DEaT PROD PROD PROD PROD PROD Finish RIH wI logging tool to 18400'. RUN USIT log from 18400' to 15400' POH wi logging tools. RD Schlumberger. RU Weatherford. RIH wi muleshoe on 31 stds 31/2" PH-6 tbg. Change over to 51/2" equipment and RIH to 18,492' PJSM Break circ. Pressure csg to 3500 psi. Test csg to 3500 psi for 30 mins. OK. PJSM. Finish RU to displace well. Pump 70 bbls hi vis mud and 80 bbls #4 diesel Displace well to #2 diesel at 6 bpm. Clean and seal ditch from shakers to pill pit. Circ to balance well. PJSM on LD DP. POH LD 51/2" DP. Used Weatherford lay down machine. Finish POH LD 51/2" DP to 31/2" XO. RIH wi 27 stds 5 1/2" DP from derrick. POH LD remainder of 51/2" DP. RD LD machine and RU tbg equipment. POH std back 21 stds of 3 1/2" tbg. Pull wear bushing. RU to test rams. Change upper and lower rams to 3 1/2". Test pipe rams to 250-3000 psi. Test witnessed by AOGCC rep Lou Gramaldi. RD test equipment. PJSM on running perf guns. RIH wi 360' Halliburton 4 5/8" Millenium guns wi stirn guns and related equipment. MU and RIH wi 27/8" and 3 1/2" completion assembly wI a 7" Baker SAB pkr, anchor seal assembly and PBR. RU Gatorhawk. Prep to install side pocket guages in 31/2" GLM. Pull 1 1/2" dummy from GLM. Install 1 1/2" Spartek gauges. RIH wi 31/2" PH-6 tbg and 31/2" completion equipment. Gatorhawk connections to 4000 psi. Approx 13,275' at midnight. Finish RIH wi 31/2" tbg. Gatorhawk connections to 4000 psi. Tag top of liner with centralizer at 16629'. Space out and land tbg. RU test equipment. Pressure tbg to 2750 psi to set pkr. Pressure annlus to 2500 psi to test pkr and csg. OK LD landing jt. Drain stack and set a BPV. NO BOPE. Break down components and stack in cellar. Move tree into sub base. NU tree. Prep to test same. Test tree and tree adapter to 5000 psi. PJSM on RU slickline. RU Halliburton slickline unit. RIH wi slickline and retrieve CAT standing valve. RIH and set Petrodat gauges. RIH and open sliding sleeve at 3200' RU Halliburton surface wel test equipment. RU BJ N2 truck. PJSM on testing Halliburton lines and equipment. Test all surface test lines and vessels. Blow down Halliburton flowlines Test BJ nitrogen lines Standby and wait on daylight. R/U return line for displacing tubing. Printed: 5/1/2003 3:20:42 PM 1/16/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) pump Bled pressure off annulus wI no success. Repressured on annulus 2 more times wlo success. RIH wI slickline to open CMPA sleeve @ 14014'. POOH. Unsuccessful in opening CMPA sleeve. RIH and open CMPA sleeve. RIH and close sleeve @ 3200'. Break circulation wI rig pump RIH wI Trico jet pump and Spartec gauges and set in CMPA sleeve @ 14014'. Flow test well wI jet pump Flow test well wI jet pump Flush test lines wI diesel RIH wI slickline and pull jet pump. POOH Wait on jet pump parts MIU jet pump and RIH on slickline Jet pump did not set. POOH Inspect runnning tool and pump RIH wI jet pump and set @ 14016' POOH wI wire/ine RIH and pull jet pump. POOH RIH to pull gauges. POOH RIH to retrieve gauges. No success. RIH wI bailer and clean out to top of gauges. Circ down tubing @ 2 bpm to clear tubing POOH. Recovered 1-2 quarts perf debris RIH wI retrieving tool and tag high Work baler and POOH RIH wI retireving tool and try to recover gauges-no success RIH w/ baler and bale to T/O gauges-POOH RIH wI retrieving tool and try to recover gauges-no success RID wireline and wait for fresh crew RIH wI wireline and close bottom sliding sleeve. POOH RIH wI wireline and open top sliding sleeve. POOH RIH wI bailer and work same. POOH RIH wI pulling tool and try to retrieve gauges. POOH-no success RIH wI LIB. POOH Modify tool RIH wI tapered prong RIH with pulling tool, POOH WIO gage, RIH w scratcher, POOH, RIH wI GR pulling tool, POOH wI gages RIH wI centralizer 1.87 od and taper prong 1.5 od while alternating pumping and bleeding. RU CTU, berms, and piping Hold pjsm, pump N2 down annulus. continue rigging up CTU 1/29/2002 1/28/2002 19:00 - 22:30 22:30 - 00:00 10:30 13:30 17:30 21:00 00:00 08:30 12:30 13:30 16:00 19:30 20:00 23:30 00:00 14:00 9:00 13:30 17:30 21:00 00:00 08:30 12:30 13:30 16:00 19:30 20:00 23:30 00:00 14:00 3.50 FRMTST PTST 1.50 FRMTST PTST 3.00 FRMTST SUN 4.00 FRMTST SUN 3.50 FRMTST SLlN 3.00 FRMTST SLlN 8.50 FRMTST SUN 4.00 FRMTST SUN 1.00 FRMTST SUN 2.50 FRMTST SUN 3.50 FRMTST SUN 0.50 FRMTST SLlN 3.50 FRMTST SLlN 0.50 FRMTST SUN 14.00 FRMTST PTST 5.00 FRMTST PTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST Printed; 5/1/2003 3;20;42 PM 1/27/2002 1/26/2002 1/25/2002 08:30 09:00 23:00 - 00:00 00:00 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 20:30 20:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 05:00 - 20:30 20:30 - 00:00 00:00 - 08:30 09:00 10:30 0.50 FRMTST CI RC 1.50 FRMTST SLlN .00 FRMTST PTST 9.00 FRMTST PTST 0.50 FRMTST OTHR 2.50 FRMTST SUN 8.50 WAlTON EQIP 3.50 FRMTST SUN 1.00 FRMTST SLlN 0.50 FRMTST SLlN 3.50 FRMTST SUN 15.50 FRMTST SUN 3.50 FRMTST SLlN 8.50 FRMTST SLlN PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST 3:30 9:00 07:00 19:00 23:00 3:30 5.50 FRMTST SUN 4.00 FRMTST SLlN 6.50 FRMTST SUN PCPTST PCPTST PCPTST 1/24/2002 1/23/2002 03:00 - 07:00 00:00 - 03:00 11:00 12:00 00:00 19:00 12:00 00:00 19:00 00:00 4.00 FRMTST OTHR .00 FRMTST PERF 12.00 FRMTST PTST 19.00 FRMTST PTST 5.00 FRMTST SLlN 3.00 FRMTST OTHR PCPTST PCPTST PCPTST PCPTST PCPTST PCPTST 01:00 07:00 08:30 09:30 07:00 08:30 09:30 11:00 6.00 FRMTST OTHR PCPTST 1.50 FRMTST SFTY PCPTST 1.00 FRMTST PERF PCPTST 1.50 FRMTST PERF PCPTST Clean pits and sand trap Hold safety meeting. Test slickline lubricator to 1500 psi Displace 20 bbl diesel from tubing through sliding sleeve @ 3200 Close sliding sleeve @ 3200'. Pump on back side to insure sleeve closed. RID lubricator Pressure tubing to 4000 psi wI nitrogen. Fired guns Flow test well to Halliburton test equipment Flow test well Fill annulus wI diesel and RIH wI slickline to close sliding sleeve @ 3200' Attempt to open CMPA sleeve by pressuring up on 9-5/8" annulus wI rig 1/22/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 2/4/2002 2/3/2002 212/2002 2/1/2002 1/31/2002 09:30 12:00 15:00 12:00 15:00 00:00 2.50 FRMTST PTST PCPTST 3.00 WAlTON PERS PCPTST 9.00 FRMTST RURD PCPTST 00:00 - 05:00 05:00 - 08:30 08:30 - 09:30 5.00 FRMTST PTST 3.50 FRMTST PTST 1.00 FRMTST PTST PCPTST PCPTST PCPTST Pump N2 down annulus and flow well. RU Dowell Let N2 bleed off and let well flow. Test N21ines to 4000# and pump N2 down annulus @ 400# with well flowing Stop pumping N2 , flow well Wait on Dowell crew to RU CTU RU CTU, PU lubricator, BOP, valves and hardline in cellar.stab tubing in head RU Dowell CTU Hold safety mtg, pressure test lines and fill coil tubing Test Dowell BOP to 3500 psi OK Pick up 'njct head make up BHA set injct head back on lubricator RIH wI coil tubing tag fill at 17506 while pumping N2 down 9-5/8 by tubing annulus taking returns to Halco tanks. wash slowly to 17,545 tag up solid cannot wash down. Pooh wI CTU. Note having trouble wI grabbers, damaging CT on way out. Cont'd POOH wI CT, Close lower master, blow dn coil wI N2 to Halco tank farm, blow dn kill &rtn line to pits, clear diesel from Dowells 3" pump and diesel hose, RD 2" killl return line, clean suction, volume, and pill pit. Prep to RD injector head and riser. RD and remove lines and hoses in celler SOS pumps N2, flow well to Halco tanks Hold pjsm RD CYU while flowing well RU slickline RIH close upper sleeve, POOH wI SL RIH wI tapered tool, tag @ 17503 POOH RIH wI PXN plug Running in hole wI PXN plug, POOH plug did not set Waiting on orders RIH wI Halco kickover tool and attempt to pull Spartec gages. Tub press 300 psi, annulus press 325 could not pull gages POOH PU Halco shifting tool and RIH and attempt to shift sleeve at 14016' Open sleeve and POOH Change shifting tools, RU Halco pump 200 bbls down annulus at 2 bpm & 450 psi to fluid pack annulus, RIH close top sleeve, POOH Halco confirm sleeve open by circ at 2 bpm. close wing valve and pump to see pressure increase on tubing. RD slickline Filling upright tanks wI OBM RD Halco line from annulus 1292 bbls mud in upright tanks. roll mud, line up back up transfer pump Displace wI 900 bbls mud @ 40 spm @ 800 psi thru Halco choke wI 200 psi back press. seperate crude rtns from diesel rtns. switch to rig pits when mud around Circ and even out mud to 8.9# heavy monitor well. well dead Set BPV, NO tree NU BOPs, set mud cross, set single gate, set double gate, set hydril, tighten bolts, hook up choke and kill lines Finish tighten up BOPs, install flow riser and drip pan Install mouse hole, hook up hydraulic hoses fill trip tank return line, hoses Printed: 5/1/2003 3:20:42 PM 00:00 02:30 23:00 - 00:00 00:00 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 12:30 11 :00 12:30 15:00 16:00 18:50 23:30 00:00 04:30 06:30 09:30 00:00 - 06:30 06:30 - 09:30 00:00 07:00 09:00 10:00 11:30 22:00 - 23:00 19:30 - 22:00 12:30 15:00 16:00 17:00 0:00 - 12:30 - 15:00 - 16:00 - 18:50 23:30 00:00 04:30 06:30 10:00 11 :00 07:00 09:00 10:00 11:30 00:00 19:30 02:30 04:00 5:00 6:00 17:00 00:00 2.50 1.50 2.50 1.00 1.00 7.00 1.00 7.00 0.50 1.00 4.00 2.50 1.50 2.50 1.00 2.83 4.67 0.50 4.50 2.00 3.50 6.50 FRMTST RURD 3.00 FRMTST RURD 7.00 FRMTST RURD PCPTST 2.00 FRMTST RURD PCPTST 1.00 FRMTST RURD PCPTST 1.50 FRMTST RURD PCPTST 12.50 FRMTST OTHR PCPTST 9.50 .50 FRMTST RURD .00 WELLSR RURD WELLSR RURD WELLSR KILL WRKOVR WELLSR KILL WRKOVR WELLSR PLGM WRKOVR WELLSR NUND WRKOVR WELLSR RURD WELLSR OTHR WELLSR RURD WELLSR OTHR WELLSR KILL WELLSR CIRC FRMTST OPEN PCPTST FRMTST RURD PCPTST WELLSR SUN WRKOVR WELLSR SUN WRKOVR WELLSR SUN WRKOVR WELLSR PLGM WRKOVR WELLSR PLGM WRKOVR WAlTON ORDR WRKOVR WELLSR SUN WRKOVR PCPTST PCPTST PCPTST WELLSR CIRC WELLSR SUN WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 1/30/2002 CTU Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ') 2/1 0/2002 2/9/2002 218/2002 2/712002 216/2002 2/5/2002 23:00 00:00 20:00 00:00 20:30 21:30 00:00 02:00 12:00 14:30 22:00 00:00 00:30 04:30 07:00 08:00 08:30 09:00 21:00 21 :00 - 23:30 23:30 - 00:00 00:00 - 04:00 20:00 07:30 09:00 09:30 12:00 11:00 11:30 13:30 14:00 15:00 20:00 00:00 07:00 04:00 04:30 18:00 18:00 - 20:00 6:00 11:30 - 13:30 14:00 15:00 20:00 00:00 07:30 09:00 09:30 12:00 16:00 11:00 21:00 00:00 08:30 00:00 20:30 21:30 00:00 02:00 12:00 14:30 22:00 00:00 00:30 04:30 07:00 08:00 08:30 09:00 21:00 23:00 04:30 18:00 20:00 8:00 1.00 FISH 8.50 FISH 4.00 WELLSR TRIP 20.50 WELLSR TRIP 1.00 WELLSR OTHR 2.50 WELLSR CIRC 2.00 WELLSR CIRC 10.00 WELLSRTRIP 2.50 WELLSR PULD 7.50 WELLSR TRIP 2.00 WELLSR MILL 0.50 FISH MILL 4.00 FISH CIRC 2.50 FISH TRIP 1.00 FISH JAR 0.50 FISH TRIP 0.50 FISH OTHR 12.00 FISH TRIP 2.00 FISH PULD WELLSR OTHR WELLSR TRIP WELLSR RURD FRMTST SUN WELLSR CIRC WELLSR CIRC WELLSR SUN 2.50 0.50 4.00 .00 2.00 2.00 1.50 0.50 2.50 4.00 0.50 2.00 0.50 1.00 5.00 4.00 7.50 4.00 0.50 3.50 2.00 WELLSR RURD WELLSR PULD WELLSR OTHR WELLSR PULD WAlTON EQI P WELLSR RURD WELLSR SUN WELLSR SEaT WELLSR SUN WELLSR SUN WELLSR RURD WELLSR TRIP WELLSR SUN WELLSR SUN PULD TRIP Printed: WRKOVR RU turn buckles & tighten, remove BPV, install test plug in tub. hanger, function test rams, RU test equipment and tools WRKOVR Test rams, floor valves, choke manifold, choke and kill lines upper and lower kelly cock to 250 I 3000-0K..Witness by State waived by J. Spaulding WRKOVR RD test equipment, pull tree test plug WRKOVR PU 3-1/2" land Jt RU to pull 3-1/2" tubing, WRKOVR Pull seals from PBR wi 205 K WRKOVR pjsm- LD hanger and 5 pups WRKOVR Wait on slick line, take thread protectors off DP and strap DP WRKOVR RU slick line and RIH to close lower sleeve @ 14000' WRKOVR Attempt RIH wI shifting tool. Unable to work tools below 7680' due to line drag. POH. WRKOVR RU stuffing box, pump in sub and tools. WRKOVR RIH wi 1 jt 31/2" tbg. Sting into PBR. WRKOVR Pump down tool string to sliding sleeve at 14016' WRKOVR Haliburton attempted to close sliding sleeve. Pump 1/2 bpm to assist in line movement. Increased rate to 2 bpm. Tbg pressured to 1200 psi wi no circ. WRKOVR Pressured annulus to 300 psi at 2 bpm. Stopped pumping. Haliburton cont' to try and work tools free. WRKOVR Pressure annulus to 2500 psi wi 16 bbbls mud. Cont' to attemping to work tools free. Tools string gradually moved up hole 30'. WRKOVR Pressure annulus to 2500 psi and bled to Opsi several times. Pressure tbg to 800 psi. Bled off pressure quickly. Tools came free. DECOMP POH wi shifting tool. WRKOVR POH LD 2 jts tbg. Break circ at 5 bpm at 2150 psi. WRKOVR Circ and condition mud at 5 bpm at 2100 psi. All diesel and crude was strung out in mud system. WRKOVR Monitor well. Pump dry job. Install stripper rubber. WRKOVR POH wi 31/2" tbg and completion equipment. WRKOVR RD Weatherford. Change elevators and top drive saver sub. Set top drive pressure. Clear floor. Set wear bushing. WRKOVR PU and RIH wi PBR retrieving tool, jars, 43/4" on 31/2" DP. WRKOVR PU and RIH w/3 1/2" DP to 17476'. WRKOVR Engage PBR and release K-anchor. WRKOVR CBU WRKOVR Circ and condition mud. WRKOVR POH wi 31/2" DP. WRKOVR LD PBR and K-anchor. Clear floor. PRT assembly. WRKOVR RIH wi 31/2" DP to top of pkr at 17482'. WRKOVR Sting into pkr and mill on same. WRKOVR Mill pkr. Total of 2.5' milled. Pkr will move up hole but not down. WRKOVR CBU. No gas in retums. Monitor well and pump dry job. WRKOVR POH to 16,630'. 20/40k drag with swabbing. WRKOVR Jar on fish. Mu top drive and rotate down and circ on fish until free. WRKOVR POH wi 5 stds. WRKOVR Monitor well. Pump dry job. WRKOVR POH wi 31/2" And 4 314" DCs. WRKOVR POH and LD fishing tools, pkr, tail pipe assembly and WL entry guide. 2 7/8" tail pipe assembly severely cork-screwed. WRKOVR PU overshot with 2 1/2" grapple, jars and bumper sub. WRKOVR RIH wi fishing assembly. Tagged pkr junk at 16644'. 5/1/2003 3:20:42 PM 2/4/2002 04:00 - 07:00 3.00 WELLSR RURD Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ') 09:30 01:30 05:30 07:00 2/15/2002 2/14/2002 2/11/2002 11:00 05:30 07:00 09:30 2/13/2002 2/12/2002 04:30 06:30 07:00 08:30 10:00 10:30 23:00 00:00 17:30 18:30 00:00 03:00 22:30 23:00 00:00 01:30 09:30 10:00 04:30 15:00 16:00 18:00 00:00 15:30 00:00 05:00 05:30 06:00 09:00 11 :00 14:30 08:30 09:00 09:30 .50 FRMTST OTHR 4.00 FRMTST TRIP 1.50 FRMTST TRI P 2.50 FRMTST OTHR 11:30 4:00 - 22:30 5:30 09:00 09:30 14:30 06:30 07:00 08:30 10:00 10:30 23:00 00:00 01:30 18:30 00:00 03:00 04:30 23:00 00:00 01:30 09:30 10:00 11:30 16:00 18:00 00:00 04:30 00:00 05:00 05:30 06:00 09:00 11:00 15:00 17:30 14:00 2.00 0.50 1.50 1.50 0.50 12.50 .00 .50 1.00 5.50 3.00 1.50 8.50 FISH TRIP 5.00 FISH TRIP 0.50 FISH OTHR 0.50 FISH SFTY 3.00 FISH PULD 2.00 WELCTL OTHR 4.00 WELCTL BOPE 6.00 0.50 1.00 1.50 8.00 0.50 1.50 8.50 1.00 2.00 6.00 4.50 9.50 .00 FISH 0.50 FISH 0.50 FISH 5.00 FISH WELLSR OTHR WELLSR OTHR WELLSR PULD WELLSR RURD WELLSR SFTY WELLSRTRIP WELLSR TRIP FRMTST TRI P WELLSR CIRC WELLSR TRIP WELLSR TRIP WELLSR OTHR WELLSR OTHR WELLSRTRIP WELLSR TRIP WELLSR PULD WELLSRTRIP WELLSR OTHR WELLSR TRIP WELLSR TRIP WELLSR CIRC WELCTL OTHR WELLSR PULD WELLSR TRIP WELLSR TRIP TRIP OTHR TRIP CIRC WRKOVR Wash down from 16,635' to 16,793'. No problems. WRKOVR RIH to 17,465'. No problems. WRKOVR Circ and condition mud while rotate and reciprocate pipe. No gas at bottoms up. Had small amount of sand, metal and coarse CaC03 in returns. WRKOVR PU and RIH wI 21 jts DP to top of fish at 18176'. No obstructions. Engage fish. Gained 12k up wt. WRKOVR POH (wet) wI guns. Minor tight spot at 16508'. WRKOVR POH w/3 1/2" DP and 4 3/4" DC's. WRKOVR Clean rig floor. WRKOVR PJSM on handling perf guns. WRKOVR POH and LD perf guns. All shots fired. WRKOVR Clear floor. Pull wear bushing and set test plug. WRKOVR Test all BOPE to 250-3000 psi wI annular to 2500 psi. Test witnessed by AOGCC rep John Crisp. WRKOVR RD test equipment. Pull test plug and set wear bushing. WRKOVR MU mill assembly. WRKOVR RIH wI mill assembly and 31/2" DP to 15000'. WRKOVR RIH w/6 1/8" mill to 18171'. Roataw from 16521' to 16712'. No obstructions. POH wI 7 stds to 17,520'. WRKOVR Circ at 5 bpm and condition mud while rotate 80 to 100 rpms and recipracating pipe 90'. WRKOVR POH wI mill. Had 30k overpull at 17,188'. Worked through wI no problems. WRKOVR Change out broken shackle on top drive. WRKOVR Std back BHA. WRKOVR LD mill assembly. Clean boot baskets. MU 6" bit and 7" csg scraper. WRKOVR RIH w/3 1/2" DP to top a liner at 16,627'. WRKOVR Ream and circulate throgh obstruction at 16,640'. WRKOVR RIH to 17,560'. POH to 17,100'. Had 30k overpull at 17,200'. RIH to 17,560' WRKOVR Circ and back ream at 80 rpms from 17560' to 16,525' Had obstructions at 17126' and 17186'. Reamedout OK. WRKOVR Circ and rotate pipe for 1 hr above liner top. Pump dry job. WRKOVR POH w/ 3 1/2" DP WRKOVR POH w/31/2" DP to BHA. WRKOVR Trouble shoot reverse on drawworks(electrical). Redress drlg line clamp. WRKOVR Cut and slip drlg line. WRKOVR Service rig WRKOVR POH wI BHA. LD scraper assembly. 1 cup pkr junk in boot baskets. WRKOVR Clear and clean floor. RU Weatherford tbg equipment. WRKOVR PJSM on running 31/2" tbg. WRKOVR MU and RIH w/3 1/2" completion assembly. WRKOVR Pkr stopped at 16,644'. PU 10k over up wt. RU to reverse circulate. WRKOVR RU circ well. Attempt to reverse circulate wI no success. Break circ the long way at 2 bpm. Pull pkr free. Work pkr into liner. WRKOVR Finish RIH slow. Tag liner top at 16,629' w/8 1/2" centralizer. WRKOVR Space and land tbg. WRKOVR Drop 1 3/4" ball and pump sown same. Pressure tbg to set pkr. Ball sheared at 2500 psi. Pressure annulus to 3000 psi OK. Pressure annulus to 3600 psi to open sliding sleeve. WRKOVR BOLDS. Shear PBR 32k above up wt (172k total). Reland tbg. LD LJ Printed: 5/1/2003 3:20:42 PM 2/10/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ') 2/19/2002 2/18/2002 2/17/2002 2/16/2002 8:00 5:30 02:00 09:00 9:00 - 00:00 22:30 00:00 00:00 01:30 15:00 18:30 21 :00 - 00:00 20:00 00:00 08:00 09:00 09:30 05:30 01 :30 - 08:00 00:00 09:30 11:00 20:00 11:00 0:00 2:30 3:00 8:00 - 20:00 21:00 00:00 02:00 01:30 15:00 18:30 22:30 21:00 09:00 0:00 05:30 09:00 09:30 19:00 01:30 11:00 20:00 00:00 2:30 13:00 5:30 7:00 11 :00 8:00 3.00 FRMTST SUN 7.00 FRMTST PTST 1.00 FRMTST CIRC .50 FRMTST SUN 13.50 FRMTST OPEN 3.50 FRMTST SUN 4.00 FRMTST SUN .50 FRMTST CIRC 1.50 FRMTST OTHR 9.00 FRMTST RURD 4.00 FRMTST SEaT 1.50 FRMTST SUN 2.00 FRMTST TRIP 3.00 FRMTST SUN 2.00 FRMTST SUN 5.50 FRMTST SUN 5.50 FRMTST SUN 2.50 FRMTST SUN 2.50 FRMTST TRI P 0.50 FRMTST SUN 2.50 FRMTST SUN 6.00 FRMTST SUN 5.00 FRMTST SUN 1.00 FRMTST RURD 0.50 FRMTST SEaT 9.50 FRMTST SUN 6.50 FRMTST CIRC .00 FRMTST CIRC Printed: WRKOVR Set BPV. WRKOVR NO BOPE. NU tree. WRKOVR Test tree to 5000 psi. RU Halliburton lines and test to 5000 psi. RU choke and kill lines and test to 3500 psi. WRKOVR PJSM. Attempt to reverse circ well wi diesel. SSSV was closed. RU pump and open valve. WRKOVR Rig reverse circ 40 bbls #4 diesel. Halliburton reversed in 1100 bbls diesel. Held back pressure on choke while displacing tbg with diesel. WRKOVR RU slickline unit and lubricator. WRKOVR Test slick line equipment to 1500 psi. WRKOVR RIH wI cat standing valve and guages. Unable to set SV due to CaC03 and debris in tail pipe. POH. WRKOVR RIH wI jet pump. Pumped down tools at 2.4 bpm. Unable to set jet pump in sliding sleeve. WRKOVR RIH wi braided line brush. Attempt to circulate tools down. Press tbg to 1900 psi. No circulation. Pressure annulus to 2750 psi. Bled tbg to 1000 psi. No annulus to tbg communication. Assume SS closed while attempting to set jet pump. Cont' RIH. Tagged hard fill at 17425'. Worked through to 17457'. Unable to jar past 17457'. POH. WRKOVR RIH wi 2.25" drive down bailer to 17460'. Work down to 17461'. POH. CaC03 in bailer. WRKOVR RIH wi sleeve tool. Shift SS open at 3212'. Cont' in hole to 17445' Attempt to open sleeve wI no success. Lost hole to 17438'.Open tbg to test tank. Bled to 0 psi. Shut well in. POH. WRKOVR Well pressureed to 280 psi. RIH and close top sleeve. Bled off well. Annulus and tbg pressure increase at same rate indicating bottom sleeve to be open. POH. WRKOVR Circulate down tbg and out annulus at 5.5 bpm wi 2000 psi on tbg and 400 psi on annulus. Pumped 250 bbls diesel/drive fluid. WRKOVR RIH wi jet pump while pumping 2 bpm down tbg wi rig. Set pump in sliding sleeve at 17445', POH. WRKOVR POH wI slickline after setting jet pump. WRKOVR Test well utilizing jet pump. WRKOVR Shut well in. RIH and retrieve test pump. WRKOVR RIH and set Cat standing valve with gauges in RN nipple at 17544'. POH. WRKOVR RIH wI jet pump. CMPL TN RIH wljet pump on 0.125" SL and set same in CMPA sliding sleeve @ 17445'MD. POOH wlsetting tool. CMPL TN Pump test well CMPL TN Rate decreasing indicating restriction to flow. Attempt to surge casing x tubing annulus. Pressure up and release @ 3500 psi wino success CMPL TN RU slickline to pull jet pump. Pull jet pump - no debris in pump CMPL TN MU SL bailer CMPL TN RIH w/bailer and work to within 4' of top of CSV in RN nipple @ 17544' MD. POOH and recovered -1 cup of CaC03 and fine metal particles from previous packer milling ops CMPL TN RIH w/2-1/4" pump bailer to top of CSV. Work bailer and POOH. Bailer had indications on muleshoe that it was worked down to CSV. Very little debris recovered CMPL TN RIH w/1-3/4" pump bailer to bail inside of fishing neck on CSV. Work bailer and pooh. Very little debris recovered. Indications on bailer mule shoe that the bailer had entered the fishing neck. 5/1/2003 3:20:42 PM 2/15/2002 Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 2/22/2002 2/21/2002 5:00 3:30 01:00 04:30 2:30 00:00 23:00 - 00:00 06:00 07:00 11:00 17:30 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 06:00 21:00 00:00 03:00 05:30 06:00 19:30 6:30 5:30 11:30 07:00 11:00 6:30 7:30 15:30 00:00 03:00 05:30 06:00 11:30 23:00 8:30 04:30 2:30 3:30 01:00 9:30 5:00 3.50 FRMTST SUN 3.50 FRMTST SUN 8.00 FRMTST PTST .00 FRMTST CIRC 3.50 FRMTST SUN 3.00 FRMTST SUN .00 FRMTST OTHR CMPLTN 4.00 FRMTST SUN CMPL TN 5.50 FRMTST PTST CMPL TN 4.50 FRMTST SUN 2.00 FRMTST PTST 2.50 FRMTST PTST 3.50 FRMTST SUN 4.00 FRMTST SUN 3.00 FRMTST SUN 3.00 FRMTST SUN 2.50 FRMTST SUN 0.50 FRMTST SUN 5.50 FRMTST PTST 2.00 FRMTST SUN .50 FRMTST SUN .00 FRMTST CIRC .00 FRMTST SUN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMP~N CMP~N CMP~N CMP~N CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN Printed: RIH on SL w/GR pulling tool to retrieve CSV. Pull CSV from RN nipple @ 17544 Run jet pump to CMPA sliding sleeve @ 17445' MD RD slickline, line up Halliburton and prepare to pump test well Pump test well. Casing injection pressure not high enough per performance curves for jet pump. Potential leak in seals around pump. RU Slickline to pull pump. (New seals installed on pump prior to this run) Pull jet pump, tear down and inspect same. No obvious indications of pump failure. RIH w/B-shifting tool to make sure upper sliding sleeve @ 3211' MD is closed. Shifting tool gave indication that it may have been slightly open üet pump latch profile very similar to profile of sliding sleeve - may have bumped it open). Make up jet pump and re-run to CMPA siding sleeve @ 17445' MD. Pump Test Hemlock Fm Pump Test Hemlock Poor pump performance (low pressure vs. injection rate) per performance curve. Pumping at 2 bpm and 1800 psi. Suspect leak in system. RIH on SL and pull jet pump from CMPA SS @ 17445' MD. Jet pump had washout inside body of jet. Rebuild pump. Run rebuilt jet pump to sliding sleeve @ 17445' MD. Pump test Hemlock. Pump pressures of 3000 psi @ 1 bpm, 3500 psi @ 1.5 bpm. Pump pressure too high for rates - suspect obstruction. Surge well down tubing/annulus to 3500 psi 2X wIno results. Pump test with no improvement. RU slickline and pull jet pump from CMPA sliding sleeve @ 17445' MD. Pump down annulus/up tubing while pulling at 1.5 bpm and 3000 psi. Pull pump and circulated @ 2.0 bpm and 3500 psi giving indication of partially closed sliding sleeve. Sleeve likely closed after pump had been set when jarring setting tool off of pump. Modify setting tool to reduce risk of same on future runs. RIH w/B-shifting tool to open lower siding sleeve (inner sleeve) at 17445'MD. POOH RIH w/B-shifting tool to close upper sliding sleeve (CMPA/CMD) @ 3212' MD. Pump down tubing/up annulus @ 5.75 bpm and 2500 psi to verify everything is clear. Finish circulating through CMPA sliding sleeve @ 17445' MD to insure sleeve is clear prior to running jet pump RIH on SL wth jet pump and set in CMPA sliding sleeve Pump Test Hemlock Formation Continuous decline of production raye and injection pressure at various injection rates on jet pump. Shut in annulus and pressure up on tubing @ 2 bpm to 2500 psi, slow rate to 1 bpm and increase pressure to 3200 psi. Shut dn pump and allow to bleed off to formation (24 bbls). Bled to 2000 psi in 15 minutes. Bleed off pressure RU Halliburton slickline, RIH w/B-shifting tool to insure upper CMPA/CMD sliding sleeve at 3211' MD is closed. Sleeve closed RIH w/GR retrieving tool and pull jet pump. Tear down pump and found similar washout in pump as found in previous pump pulled on 2/21/2000. Download pressure data and determine washout occured in 2 hours at BHP of 840 psi. Suspect cavitation in pump body as primary factor of washout. 5/1/2003 3:20:42 PM 2/19/2002 2/20/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 2/25/2002 02:00 23:00 - 00:00 00:00 - 02:00 5:00 20:00 15:00 11:30 18:30 - 20:00 23:00 18:30 03:00 .00 FRMTST RURD CMPL TN .00 FRMTST SUN 2.00 FRMTST SUN 3.00 FRMTST SUN 3.50 FRMTST CIRC 3.50 FRMTST SUN .50 FRMTST CIRC CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN Printed: Establish circulation thru lower sliding sleeve; pressured up to 3500 psi on backside @ 2 bpm. Pressured dn tubing to 3300 psi - no circulation. CMPA sliding sleeve @ 17445' may have shifted closed when pulling shifting tool out. Run B-shifting tool to open lower sleeve (opens upper sleeve on way in); then reverse tool and close upper sleeve Pump down tubing w/rig pumps @ 2 bpm. Pressure increased to 3500 psi after 25 strokes. Release tubing pressure and pump down casing w/Halliburton - pressure increased to 3500 psi with no increase on tubing. Bleed off pressure. RIH w/shifting tool and open upper sleeve. Pressure down tubing and equalize to annulus thorugh the 3/16" port in the upper sleeve. Slow equalization time indicated bottom sleeve closed or packed off above sleeve. Continue in hole with shifting tool to lower sleeve and shift down to open (tagged plug 5' above SS and worked 20' below SS). Pull slowly up to avoid closing lower sleeve. Pressure up on tubing and saw immediate equalization to annulus indicating bottom sleeve open. POOH with shifting tool, reverse tool and RIH and close upper sleeve. Pressure on tubing to insure lower sleeve is closed. Pressure increased @ 1 - 2 bpm to 3500 psi and held. Bleed pressure off tubing and pump down annulus w/Halliburton to 3500 psi @ 1 - 2bpm and hied. Rocked tubing and casing with no change indicating either bridge in tubing, bridge in annulus or closed sleeve. RIH w/drive down bailer and tagged up hard @ 17254' (SS @ 17445, packer @ 17502', RN nipple @ 17544'). Worked bailer. Recovered -5 Ibs of CaC03 and fine metal filings. Make 2nd bailer run. Tagged up hard @ 17234' (lost 20'). Work bailer. POOH w/drive down bailer from 17234'. Recovered -2 qts CaC03 from bailer RD Lubricator and RD slickline unit 5/1/2003 3:20:42 PM 10:30 11:30 .00 FRMTST CIRC CMPL TN 10:00 06:30 00:00 01:30 05:30 10:30 01:30 05:30 06:30 10:00 0.50 FRMTST SUN .50 FRMTST PL T 4.00 FRMTST SUN .00 FRMTST CIRC 3.50 FRMTST SUN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN Reverse shifting tool, RIH on slickline and close top CMPAlCMD SS @ 3211' RIH w/BH fluid sampler on slickline to top of obtain BH sample. RIH w/BH fluid sampler and pull sample RIH w/pulling tool and retrieve gauges from RN nipple @ 17544' RU Halliburton and circulate down annulus thru upper SS @ 3211 clear system to power fluid. RIH on slickline w/B-shifting tool and open bottom CMPA SS @ MD 17445' to 2/24/2002 RIH w/B-shifting tool to lower sliding sleeve and close same. RIH w/drive down bailer to check tubing tail and perf interval for plugging/fill. Pressure test tubing x casing annulus to 3500 psi f/10 minutes to verify sleeve closed while making bailer run. OK. Run drive down bailer on SL below tail pipe. Tagged up fairly solid @ 17898' MD (bottom perf @ 17915' MD). Recovered CaC03 and fine metal - -1/2 qt. Run gauges to RN nipple @ 17544'. Run B-shifting tool to upper CMPAlCMD sliding sleeve @ 3211 and open same for N2 lift. Test BJ lines to 4000 psi - OK. Perform N2lift 750 scf initial rate. Drop to 330 scfd rate 20:00 05:30 - 20:00 00:00 4.00 FRMTST SUN 4.50 FRMTST PTST CMPL TN CMPL TN RN nipple @ thru sliding sleeve @ 7544 to 2/23/2002 01 :00 - 04:30 04:30 - 05:30 00:00 01:00 3.50 FRMTST SUN .00 FRMTST SUN .00 FRMTST SUN CMPL TN CMPL TN CMPL TN MD 2/22/2002 18:30 - 22:00 22:00 - 00:00 3.50 FRMTST SUN 2.00 FRMTST SUN CMPL TN CMPL TN Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: Printed: 5/1/2003 3:20:42 PM 2/27/2002 2/26/2002 07:00 - 09:30 06:30 - 07:00 04:00 00:00 - 00:30 00:30 - 04:00 23:00 - 00:00 22:00 - 23:00 00:00 01:00 02:30 20:30 - 00:00 20:00 - 22:00 5:00 12:30 14:00 19:00 - 20:00 14:00 15:00 01:00 02:30 2:30 06:30 19:00 2.50 CMPL TN NUND CMPL TN 0.50 2.50 2.00 4.00 .00 .50 10.00 3.50 0.50 3.50 .00 .00 .50 WELLSR RURD CMPL TN .00 CMPL TN SEaT CMPL TN WELLSR SEaT CMPL TN WELLSR OTHR CMPL TN WELLSR AWSH CMPL TN WELLSR SEaT CMPL TN .00 WELLSR DEaT CMPL TN WELLSR PLGM CMPL TN WELLSR RURD CMPL TN WELLSR SFTY CMPL TN WELLSR RURD CMPL TN WELLSR AWSH CMPL TN WELLSRAWSH CMPLTN WELLSR OTHR CMPL TN WELLSR OTHR CMPL TN Prepare rig and pad to rig up CTU; WOCTU PJSM. RU BJ CTU. Stab pipe into injector, dimple on CT connector, RU pump, berm pump and CTU, pull test connector, rig injector to WH, NU and function test BOP PJSM. Blind ram test, set counters, load coil w/diesel, pressure test hard lines to 4000 psi, PT against swab valve to 2500 psi, PT WH assembly to 4000 psi. Test blind rams, tubing rams (500psi & 4000 psi) Pull test coil 50' on TIH and pump 5 bbls to establish circulation RI H with coil to top of CaC03 fill above SS @ 17234. Start washing with alternate slugs of 3 bbls xylene followed by 12 bbls 15%HCI acid. Wash down to tubing tail @ 17544'. Drop ball to open nozzle to tornado jet. Pull up to SS @ 17445' and pumped last of xylene acid slugs. CaC03 unloaded into tubing, chasing up hole17526'. Attempted to wash thru but tagged up hard and could not wash through. Wash back down through bridge to tail. Work from above SS to tail 5 times wIno problem. POOH with CTU holding 300 psi on tubing. RD CTU Injector and CT BOPS RU Halliburton slickline lubricator and sheaves. PT lubricator to 500 psi. Hold pressure on lubricator. Begin berming for Dowell acid skids and pump. RIH w/RN plug wlequalizing prong to RN nipple. Set plug in nipple, shear out and POOH with SL. RD slickline and lubricator. (NOTE: after setting plug it was discovered the CTU tornado jet had sheared from the disconnect. Tornado jet is -1.25" 00 and -1' long and is in the rathole below the tailpipe) Pressure test down tubing to 4000 psi monitoring backside as indication of open sleeve. Annulus pressure tracked tubing pressure; both sides equalized @ 3750 psi. Hold pressure for 10 minutes. Bleed pressure off annulus. MIRU Dowell acid unit, acid transports and pumping van. Begin laying lines for transfer and prepare to premix acid. SO for operational planning, coordination, and safety meeting w/BJ Coil, Dowell, Nabors and Halliburton testers. Discuss sim-ops, fluid transfer and pumping/displacement objectives and logistics. NU BJ coil lubricator to and blow down CTU thru choke w/N2 to Halliburton tank. RD BJ coil unit. Transfer power fluid from Nabors pill pit to tank farm, transfer acid tank bottoms from BJ lines and tanks to Dowell acid and xylene tanks. Transfer power fluid from Halliburton lines to BJ to tank farm. Lay lines from Dowell to tree. Monitor tubing pressure during rig up and ops meeting - 4 hours, 0 psi. Drain power fluid from rig pill pit a send to Halliburton tank farm Set CTU lubricatorRU BJ N2 service and blow down coil w/nitrogen back to Halliburton tank farm PJSM. Pump 157 bbls 15% HCI/25% xylene down tubing through sliding sleeve @ 17455' MD and displace with 121 bbls of power fluid via the rig pump to the sliding sleeve. SI w/63 psi on tubing SWI to let acid work on CaC03 in annulus. TO acid @ 14482' MD, planned setting depth for packer on Starichkoff completion @ 16526' MD, planned setting depth for sliding sleeve on Starichkoff completion @ 16424' Open up on tubing and allow well to equalize (67 psi on tubing). BPV. NO tree Set 2/25/2002 03:00 2:30 12:30 20:30 9.50 8.00 WAlTON EQIP CMPLTN WELLSR RURD CMPL TN Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) Printed: Pull bpv and set tree plug. Test tree to 5000 psi. from/to tank farm and test same to 250/5000 psi 5/1/2003 3:20:42 PM 0:30 04:00 - 05:30 05:30 - 09:30 09:30 - 10:30 12:00 .50 CMPL TN SEaT CMPL TN .50 CMPL TN OTHR CMPL TN 4.00 CMPL TN NUND CMPL TN .00 CMPL TN NUND CMPL TN 3/2/2002 02:30 - 04:00 00:00 - 02:00 02:00 - 02:30 09:30 - 00:00 08:30 - 09:30 03:00 - 03:30 03:30 - 08:30 0.50 CMPL TN SFTY CMPL TN 5.00 CMPL TN PULD CMPL TN Finish POOH w/3-1/2" PH612.95 ppf P-110 tubing Layout PBR stinger, clean floor, lube rig and prep to RIH w Tyonek /completion PJSM on handling guns. PU 500' of 3-3/8" Halliburton Millenium TCP guns, 6 spf @ 120 phasing, slotted liner tailpipe (2 joints) 8-1/2" L TP spaceout centralizer and RN nipple (cat standing valve ran in place for pressuring up to set packer) WO Baker to round trip the CMPA sliding sleeves to Kenai to be inspected, re-dressed and pressure tested. Planned delay RIH w/3-1/2" completion to last stand. Perf interval 16965 - 17465', 7" liner top @ 16629', slotted liner joints @ 16788 - 83, 16542 - 69, 9-5/8" RN nipple @ 16567',9-5/8" packer @ 16525', GLM w/ gauges @ 16469', bottom CMPA sliding sleeve @ 16432', top CMPA sliding sleeve (outer sleeve pinned open w/ 3/16" port) @ 7012'. Finish running 3-1/2" completion string Tag L TP with 8.5" space out centralizer. PU to space out 4' above L TP. Space out and land tubing. Last upwieght=152M, SO=70M. Pressure up against standing valve to 3400 psi to set packer - backside shut in. Attempt to pressure test backside resulted in flow up tubing indicating CSV had floated off seat and initial pressure down tubing pressured up entire system. Open annulus and pressure down tubing to 3400 psi and set packer. PT annulus to 2500 psi (lower CMPA outer sleeve set to shear at 3860 psi). ines and set BPV Drain stack, rig down NO BOPE Pick up tree and set in place and NU same MU Halliburton lines .50 CMPL TN PCKR CMPL TN 2.00 CMPL TN PULD CMPL TN 0.50 CMPL TN SOHO CMPL TN 14.50 CMPL TN RUNT CMPL TN CMPL TN .00 WAlTON Eal P 3/1/2002 00:00 - 02:30 02:30 - 03:00 2.50 CMPLTN TRIP 0.50 CMPLTN TRIP CMPL TN CMPL TN 14:00 - 00:00 10.00 CMPLTN TRIP CMPL TN Halliburton Prep floor, mousehole & vac system for TOOH LD 20 jts 3-1/2" PH6 tubing and SSSV from 354' pup joints TOOH w/16,OOO' of 3-1/2" sleeve. PH6 tubing string. LD top CMPA sliding 2:00 2:30 11:30 09:30 12:30 14:00 2:00 11:30 0.50 CMPLTN OTHR CMPLTN .50 CMPL TN PULD CMPL TN 2.00 CMPLTN CIRC 0.50 CMPL TN RURD CMPL TN CMPL TN 2/28/2002 07:00 - 08:00 08:00 - 09:30 09:30 0:30 10:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 07:00 .00 CMPL TN NUND CMPL TN .50 CMPL TN OTHR CMPL TN .00 WAlTON ORDR CMPLTN 11.50 CMPL TN NUND CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN SEaT CMPL TN 7.00 CMPL TN SEaT CMPL TN WOO regarding additional Hemlock testing possibilities NU BOPE. Blow down Halliburton test lines and remove same Pull BPV Fill stack and RU to test BOPE. Test BOPE 250/3000 psi. Function test Koomey and test all chokes lines and valves. Test witness waived by Jeff Jones, AOGCC. Break down flowline and drilling nipple and silicone API gaskets MU landing joint and pull tubing hanger to floor and inspect, disconnect SSSV control line from hanger & pump up on same to 5000 psi to open SSSV. Make up cement lines to head pin and back to Halliburton PJSM. Close annular and pressure test backside to 500 psi w/Halliburton. Open choke to tank farm and reverse out 120 bbls to tank #4 (power fluid) @ 3.25 BPM & 840 psi. Reverse out Acid to tank #9. Max pressure of 1271 psi after 151 bbls reversed out. Final circulating pressure 850 psi @ 3.25 bpm. pH of 3.0 - 4.0 on acid returns. RU Weatherfor and prepare to TOOH w/3-1/2" tubing RU vac truck and suck down Halliburton line back to head pin. RD LD mousehole and 2 2/27/2002 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: Printed: 5/1/2003 3:20:42 PM 05:00 8:00 3.00 WAlTON ORDR CMPL TN WOO. Vac truck couldn't keep up w/rig pumps in transferring reserve pit to rig pitsfor disposal. Fill pits w/vac truck Continue to dispose fluids. Move out Halliburton test equipment. 3/12/2002 3/11/2002 3/9/2002 3/10/2002 02:00 00:00 - 02:00 00:00 08:00 04:00 - 08:00 5:15 - 22:00 00:00 - 04:00 22:00 - 00:00 00:00 11:00 14:30 5:30 6:00 7:30 12:30 14:30 8:00 - 00:00 00:00 15:30 16:00 17:30 00:00 14:30 12:30 05:00 11:00 18:00 14:30 3.00 2.00 3.50 14.50 11.00 .00 CMPL TN SUN CMPL TN 0.50 CMPL TN OTHR CMPL TN 1.50 CMPL TN RURD CMPL TN 6.50 WAlTON ORDR CMPL TN 4.50 CMPL TN SUN 4.00 CMPL TN SUN 4.00 CMPL TN SUN 2.00 CMPL TN SUN 2.00 CMPL TN DEQT CMPL TN 6.75 CMPL TN SUN 3.00 6.00 WAlTON ORDR CMPL TN WAlTON ORDR CMPL TN WAlTON ORDR CMPL TN WAlTON ORDR CMPLTN WAlTON ORDR CMPL TN WAlTON OR DR CMPL TN WAlTON ORDR CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN CMPL TN luid RIH with PR prong, pressure build up slowing, bled tubing/ annulus pressure to zero and jar down to set prong in plug body, could not effect seal. Appied 700 psi to tubing and jar down on prong. Pressure test to 1000 psi, ok, bled off, no flow. Pulled running tools into lubricator and closed swab valve. Tested tubing/casing (sliding sleeve open) to 3800 psi, bled to 2800 psi in 10 min. Retest to 3800 psi, same result. RIH with 2.56" shifting tool, jar down through CMPA sliding sleeve @ 16431'. Bled off 510 psi from tbg/csg pull up and close sliding sleeve. Jar down through sliding sleeve and RIH to PR prong. Applied 550 psi to tubing ( casing pressure 60 psi) and jar down on prong for 30 minutes. Bled tubing to zero and shut in tubing. Tubing pressure built to 120 psi in 15 minutes. POH with shifting tool. RIH with 2" SB pulling tool to 16544' slm, engage prong and POH, recovered prong. Packing seals on prong indicated only partial seat. RIH with 2.5" GR retrieving tool and latch into PRN plug body @ 16553' slm. POH recovered plug body. RIH with RNN plug to 16553' slm jar down to set plug (30) min. POH, found plug had not sheared off. Redress and rerun RRN plug, plug hung up in sliding sleeve @ 16431'. Applied 500 psi to tubing and RIH to 16553' slm. Appeared to open sliding sleeve with plug assembly. Confirmed sleeve opened by annulus to tubing communication on SCAN system. - increased applied pressure to tubing to 750 psi, jar down on plug for 45 minutes. Bled tubing pressure to 400 psi after set appears good. Pressure appeared to hold. Pooh. Confirmed plug was set. Pressure test tubing and casing simultaneously to 3800 psi for 30 minutes. Bled off system to Halliburton tanks to zero psi. Open tubing and casing valves at wellhead and monitor well static. Rig down Halliburton slickline tools and lubricator. Install BPV in tubing hanger. Rig down Halliburton hard lines from wellhead - remove from cellar. Waiting on possible change of scope from Anchorage. Continue to rig down Halliburton testing equipment. Rig up to initiate annular disposal - prepare mud tanks for waste fluid from reserve pits. Continue rig down of Halliburton equipment and hard line. Transfer 600 bbls from oil reserve pit to rig mud tanks. Transfer 800 bbls of crude/power fluid to Tesoro. Move 80 bbls power fluid to pill pit for pipe displacement, if necessary. WOO. Continue to RDMO Welltest equip. Transport remaining crude/power fluid to Tesoro. WOO. Begin annular disposal operations from invert oil base mud pit. Continue RDMO Halliburton testing equipment. WOO. Annular disposal of fluids from invert oil based mud pit. Pump w/rig pump @ 1230 psi & 3 bpm. New Volume Disposed this 24 hours: 1362 bbls. Previous Volume Disposed: 7867 bbls. Cumulative Annular Disposal this well: 9408 bbls WOO. Disposing fluids from invert OBM pit down 9-5/8" x 13-3/8" annulus. rom 3/8/2002 11:00 15:15 4.25 CMPL TN SUN CMPL TN Legal Well Name: HANSEN #1 Common Wen Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ') 7:00 8:30 18:30 - 00:00 .50 ABANDt\ TRIP DECOMP 5.50 ABANDt\ NUND DECOMP Printed: Rack and strap 120 jts 3-1/2" SLHT tubing. pickup tubing, PJSM. RIH w/ slht tubing open ended. 10 BBL water/oil spill(5 bbl outside containment) on ice of pad. Valve left open to gunline while transferring fluid for injection from pits to pump suction pit. Spill reported and cleaned up. Fluid consisted of 90% water/1 0% oil mud from cuttings storage pit. Finish RIH w/8rd EUE tubing on top, m/u hanger and land. Nipple down choke line, kill line, injecting cuttings pit fluid down 13-3/8 5/1/2003 3:20:42 PM 11:00 6:00 6:00 7:00 5.00 ABANDt\ TRIP DECOMP .00 ABANDt\ OTHR DECOMP 09:00 05:30 06:30 07:30 08:30 11 :00 06:30 07:30 08:30 09:00 2.00 ABANDt\ OTHR DECOMP .00 ABANDt\ PULD DECOMP Pull wear ring and clear floor. .00 ABANDt\ OTHR DECOMP Rig down lay down machine & deadman. .00 ABANDt\ OTHR DECOMP Lay down subs, extra lift subs from rig floor. 0.50 ABANDt\ OTHR DECOMP R/U weatheriord tongs, remove collar from it # 1203-1/2" SLHT and install collar xo. WAlTON OR DR CMPL TN Obtain verbal approval for well suspension program from AOGCC WAlTON OTHR DECOMP Finish disposal of volume in rig pits. Diposal volumes as follows: 3275 bbls Daily Volume, 12,683 bbls Cumulative Volume for this Well, 1280 psi Ave Daily Pressure @ 3 bpm. CMPL TN NUND DECOMP PJSM. NO Tree & NU BOPE CMPL TN NUND DECOMP PU flow nipple, hook up flow line, trip tank lines, bleed-off line, turn buckles, choke and kill lines, drip pans. Function test all rams. BOP test waived by Jeff Jones, AOGCC WELCTL BOPE DECOMP Rig up to test, test blinds 250/3000, pull plug out of hanger, plu test joint, suck stack dry, test jt blind sub woulod not screw into hanger(sub's pin milled to thick) pull back pressure valve. Test all ram's and valve's to 250/3000 psi, rig down test equipment. CMPL TN PULD DECOMP Rig up to pull test string, unseat tubing from packer (204K), pull tubing head and break down. CMPL TN PULD DECOMP R/U Weatheriord lay down machine. CMPL TN PULD DECOMP POH UD 3-1/2" PH-6 tubing. ABANDI\ PULD DECOMP Continue POH UD ph-6 tubing. Wipe each jt of oil and plug each end w/oil sorbents. Trucking to weatheriord in Kenai. ABANDI\ PULD DECOMP UD 4-3/4" drill collars in mousehole. ABANDt\ PULD DECOMP P/U Baker N-1 bridge plug & setting tool and make up. ABANDt\ OTHR DECOMP Set wear ring. ABANDt\ OTHR DECOMP Change out saver sub on top drive. ABANDt\ TRIP DECOMP RIH wlbridge plug on 3-1/2" drill pipe. Continue cleaning test tanks and prepare for trucking to slope. All halliburton test equipment offsite. ABANDt\ TRIP DECOMP Continue RIH w/Baker N-1 bridge plug on 3-1/2" drillpipe to 16450'. ABANDI\ DPST DECOMP Drop ball, pressure to 1500 psi, pull 20K over & shear & set, bridge plug set @ 16450' top of plug, open kill line & pressure both sides to 3500 psi. Hold 3500 psi f/30 min-good test. ABANDt\ PULD DECOMP PJSM, laydown procedure, rig up lay down machine. ABANDt\ PULD DECOMP POH lid drillpipe. ABANDt\ OTHR DECOMP Blowdown top drive, kill line, monitor well. ABANDt\ PULD DECOMP Continue poh lId drillpipe. ABANDt\ TRIP DECOMP RIH 11 stands in derrick. ABANDt\ PULD DECOMP Continue poh I/d drillpipe. ABANDI\ OTHR DECOMP drillpipe plugged, could not pump down drillpipe. Pressure to 3500# & attempt to reverse circ. Pipe still plugged, continue to poh w/dp wet. ABANDt\ OTHR DECOMP Blow down kill line, top drive, clear floor. ABANDt\ PULD DECOMP Lay down 3-1/2" drillpipe wet, 98 jts.Lay down Baker tool. R/U catwalk & ines to 3/16/2002 3/15/2002 3/14/2002 3/13/2002 00:00 00:30 00:00 - 03:00 03:00 - 04:30 3:00 5:30 00:00 20:00 - 00:00 00:00 - 05:00 04:30 05:00 06:30 07:00 09:00 09:30 22:00 0:00 05:00 3:30 4:30 5:30 6:00 6:30 5:30 00:00 13:30 14:30 15:30 16:00 16:30 00:00 00:30 05:30 05:00 06:30 07:00 09:00 09:30 22:00 00:00 3:00 0:00 0.50 5.00 0.50 1.50 0.50 2.00 0.50 2.50 2.00 3.00 .50 2.50 8.50 3.50 4.00 5.00 3.00 5.00 .00 .00 0.50 0.50 7.50 setting sleeve and 3/12/2002 05:00 8:00 18:00 20:00 3.00 2.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 7/3/2002 7/2/2002 7/1/2002 00:00 00:00 00:00 - 00:00 00:00 00:00 24.00 24.00 24.00 SUSPEN Printed: out. Suck out cellar, run over shakers, fluid to suction pit, Suck out sand trap, continue cleaning pits. Scrub derrick w/soap, pressure wash to clean lower 1/3 derrick, move pit liner and berm under board. Continue to scrub & pressure wash board windwalls, doghouse and girts. Oil coat & shrink wrap drilling line spool. Oil chain and air motor. Grease hydraulic control arm, shrink wrap motor. Wash iron roughneck, checked out w/mechanic and grease, prepare for stackout. Clean #3 mup pump, tear down & clean A#2 mud pump, pull suction end and clean out. Magna flux seats of #2 mud pump. Rig down, winterizing equipment, continue washing oil base mud off derrick & pits. Blow down draw works w/air & anti-freeze. Rig down Epoch monitors and equipment. Finished shipping out test tanks, oily waste bags, sample containers, etc. Install gate at entrance. Rig up Unit. Crews on location @ 09:30. Roll out herculite and nail down. MIRU GIS. Release all trucks by 15:00 hrs. Release crane @ 20:00 hrs. Work on muc pump calibration, RU hardline. Offload 100 bbls of fresh water. Note: Pacfic Detroit Diesel generator showed on location wlo fuel (as requested). Once running, found that one of the feed lugs was stripped out. Will call ASAP in a.m. Waiting on parts to rig up water tank from Oilwell. Finish building containment, running hardline to well. Check freight from Oilwell and AK Pipe. Unload Carlisle trucks. Add "Clean Up" to pits, roll same and clean up junk or film in pits. Welding on system. Make final connection to well head, install air compressor in containment. Modify riser to shakers for LWT. Test run PIT HOG equipment. Everything ran fine. Had to change locations of spray bars. Made 3 new headers with nozzles on BEM 3 shaker. This will allow us to thoroughly wash gravel if a little mud is running over shakers. 5/1/2003 3:20:42 PM 3/19/2002 3/18/2002 00:00 - 00:00 23:00 00:00 01:00 6:00 - 23:00 11:30 11:30 14:00 00:30 18:00 18:30 00:00 01:00 8:00 18:30 00:00 14:00 16:00 24.00 RIGMNT OTHR DEMOB .00 ABANDt\ NUND DECOMP .00 WELLSR DEQT ABANDN 7.00 RIGMNT OTHR DEMOB 2.50 ABANDt\ RURD DECOMP 2.00 ABANDt\ NUND DECOMP 11.00 ABANDt\ RURD DECOMP 7.00 ABANDt\ NUND DECOMP 0.50 RIGMNT OTHR DEMOB 5.50 RIGMNT OTHR DEMOB X 9-5/8 casing annulus. Rig down topdrive. & set back pressure valve. Organize floor, prepare to Jay down tesco top drive. PJSM, continue injecting down annulus. UD mousehole, rig down tesco top drive, breakout xo's from swivel to top drive, I/d top drive, I/d swivel, I/d service loop, I/d misc. pups, subs, lId tesco rail, clean all pieces before laying down. UD clear floor of rental tools & equipment. Take beaver slide & cat walk down to make rooom to get bop's out of cellar, install trolley to move bop's out. Nipple down bop's, wash oil base mud f/stack, remove rams & wash out obm. P/U tree & make up, pull bpv & set tree test plug, test hanger & tree. Rig up test pump manifold to top of tree, test to 5K f/10 min, good test. Flush mud pumps #1,2,3, tear down mud pump #3, clean pits, remove choke hose, blank open ends on choke. Wash down front windwalls, cleanout girts in derrick. Lift stand pipe & tighten clamps. Rig up bridle lines, Rig up yoke. Lay down mud bucket, wash down floor, clean shakers. Prepare floor to lay derrick over, Rig down front wind walls, remove front floor plates, put air tugger away in top sub. Tie lines back in derrick. Continue cleaning shaker & pits. Lay derrick over on stand. Tie off blocks, drilling line, tugger lines, etc. Build berm under derrick to catch wash water. #2 mud pump taken apart to winterize for stacking 3/17/2002 00:00 - 00:30 0.50 ABANDt\ OTHR DECOMP 3/16/2002 8:30 - 00:00 5.50 ABANDt\ NUND DECOMP FMC torqued hanger bolts Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 7/9/2002 7/8/2002 7/7/2002 7/5/2002 7/4/2002 7/6/2002 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 - 00:00 00:00 00:00 00:00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: Unclog #1 gun line in process pit. Empty pits again and mark all nozzle locations on gun lines. Install an 'oops' line on shakers. All spray nozzles were disassembled and relocated. Unclog gunline. Made a batch of wet gel to blind off shaker gates, MTS-14 mill chute leaked bad so we gelled it off as well. Made a new line off of vertical galigher pump, to trf back to the reserve pit. Took on cuttings from dredge. I believe that the max we can wash is 5 yds. of cuttings per hour. The shakers can wash faster but the dredge pump outruns us at about the aforementioned rate. Night time dredge operator is having a hard time finding the happy medium that the daytime guy seems to find rather easy. Swaco crews installed 2" filter basket in line on water line feeding our spray bars. We are only using the bars on the BEM350 to wash with, therefore cutting our water consumption down to about 25 BBlS per hour according to my rough estimate. Will be conveying firmer numbers as we progress. Began dredging at 0600. Modified spray bars are working fine. Continuing to conserve water. Added tee to gallager pump discharge for gun and trf capabilities. This should reduce sand off in slop tank. Adjusted pump mount on process pump. Checked slop tank agitator shaft for bent, see no problem, will watch closely. Had welder (Phillips) modify cuttings buckets for dumping ease. Process is getting bugs worked out quickly. Shut down for 3 hours to add above mentioned gun and pump outprocess pit and check slop agitator shaft. Continue dredging, monitoring pit, conserving water and processing cuttings. Total cuttings processed = 9 yards. Today = 9 yards Total cuttings processed=25 yards; tOday=16 yards. Processed cuttings as per normal. Production is rising at good rate. Performed maintenance on Swaco equipment. Added 2 more spray bars to BEM350 to wash better and dry more efficiently. Training for local people on dredge is going well. Should be able to send lWT home soon. Found blown a-ring on Dredge at 1900 hrs, causing about a cup of hydraulic fluid to leak past. Installed diaper on dredge into reserve pit containment. We were able to recover all fluid with Absorbents in a timely manner. We have ordered replacement parts for dredge and they should be here within 24 hours. We will also swap out hydraulic oil to environmentally safe oil while we are down. lWT Dredge down from 1900-2400 hours; valve body leaking, waiting on parts. Total cuttings processed =25 yards. Today = 16 yards Helped Dredge guys pull hydraulic unit from their machine. Pulled apart valve body and solvent bathed same. Tried to find a-rings locally to no avail. Package from the states will be in Kenai at noon tomorrow. Swaco Bob will expedite them down to the site. Swaco crews took advantage of down time to finish some safety things on unit. Also, welder Bob is finishing some projects up. Dredge unit down from 1900 hrs last night to around 1800 hrs tomorrow. Total cuttings processed = 25 yards. Today = 0 yards Swaco crews performed maintenance on equipment. Changed out bent agitator shaft, waiting on spare to be built. Pulled off belt guards and took numbers from belts for spares. Checked fluid levels on conveyor pumps and agitators. Got started processing at 1830 hours after installing new a-rings. Should be good to go. 15 yards washed for cumulative total of 40 yards. Dredge machine was down until 1830 hours. Total cuttings processed = 40 yards. Today = 15 yards 5/1/2003 3:20:42 PM 7/3/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: 7/16/2002 00:00 00:00 24.00 Printed: room for Swaco parts and use. Environmental walk-thru and housekeeping. Sent two safe guard tanks (units #25 and #8) and vac lid to Osprey. Received one 13 BBL tote in exchange to use as vac tank, vac lid to be shipped 7/16/02 from Osprey. 0 yds processed; total 122 yds; fresh water consumed = 0 BBL. Performed maintenance on unit. Electrician wired in lights over pits and 5/1/2003 3:20:42 PM Dredge out of service, waiting on parts. [Dredge down from 6:00 AM 7/14/02 waiting on shaft seal and impeller.] Performed maintenance on unit. Installed light junction boxes over pits and recepticals in preparation for electricians arrival. Clean out connex to make more 7/15/2002 00:00 - 00:00 24.00 Process rluids until 6:00 AM. Took dredge out of service at that time due to mechanical seal failure. Atempted to find seal locally; unsuccessful. Seal due in today. Performed maintenance on unit built stantion for flourescent light. Installed new agitator shaft in injection suction pit. Agitators rotating in wrong direction, will remedy on generator oil change today. Started running conduit for pit lights. Preparing for electricians arrival. Jason Crowell (HSE) brought out Waste Management book. Dredge down from 8:00 AM. Waiting on parts. 3 yds processed, total = 122 yds. Fresh water consumed = 2 BBL hour. 7/14/2002 7/13/2002 7/12/2002 7/11/2002 00:00 00:00 - 00:00 00:00 00:00 - 00:00 00:00 00:00 24.00 24.00 24.00 24.00 Performed daily maintenance on all equipment. Continued to wash cuttings and take fluid returns to reserve pit. Took measurements for the installation of eliminator mill. Had crew change today. Welder Bob is staying over for a few days to do a few welding projects. Will probably fly home with Mike on Friday or Saturday. 25 yards washed for an accumulative total of 65 yards. Dredge was down from 1400 to 1800 hours, hose packed off with solids. Total cuttings processed = 65 yards. Today = 25 yards Rigged up Schlumberger on well @ 1000 hrs to perform logs. Waited on FMC until 2000 hrs to pull back pressure valve. RIH w/Schl temperature log and performed baseline temperature log 5320-5000' w.l.m., RIH park temp tool @ 5200' while injecting. Tested injection line to 5000 psi. Began fresh water preflush @ 2230 hrs. Pumped @ 1.8 BPM, 1300 PSI @ pumps, 1050 PSI @ wellhead (14.3 PPG E.M.W.). Wait on FMC, unaware of BPV set in tbg hanger. Injection of 160 BBLS showed temp decrease on temp log. Process cuttings, dredge having difficulty finding any quantity of matI. Changed nozzles in injection pit to 1". Serviced injection pump, checked fluids, rod oiler operation, checked levels on drive motor, etc. Tech came out to service injection pump chart recorder, was able to get it operating properly. Environmental cleanup around unit. 1-1/2 hrs down time removing loose piece of pit liner material f/suction on dredge. 20 yds processed, total 110 yds. Fresh water consumed = 15 BBL hour. Process cuttings, very little coming across. Service unit. Environmental and house-keeping cleanup. Had welder make shroud cover over pen recorder on injection pump. Primered. Built and installed door between office and sleeping qtrs. Organize office. Some cuttings w/cement in North end water base pit, can't dredge. About 6' of water in WB pit. Dredge has been worked lengthwise & across pit to recover cuttings. Use water in WB pit once solids settle to process OBM pit for G&I. 9 yds processed. Total + 119 yds. Fresh water consumed 2 BBL hour 7/10/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ...... ... > ..... ) r ........ ,. ......... ) ) 7/23/2002 7/22/2002 7/21/2002 7/18/2002 7/17/2002 7/20/2002 7/19/2002 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 00:00 - 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: shaker, reversed rotation of agitators. Dredge operational at 1700, tested operation in water pit, crane moved dredge to oil base pit to prepare for grinding operation. Waiting on an oil resistent hose for dredge. Rigging up unit to begin grinding operation. Rig manifold on water pump to use for water tank or to bulk slurry tank (enroute). Dredge operable at 1700 hours, waiting on oil compatible hose. 0 yds processed. Total 122 yds. Fresh water consumed = 0 BBLS. Perform daily maintenance on unit. Re-plumb Gallegher to mix pump crossover. Rig up 25 bbl Tote for vac use. Route circulation hose from unit thru containment berm. Doing welding projects on unit, before oil base introduced. Crew changeout J. Robbins and P. Julianov went to town; B. Crawford and J. Dare came in. Waiting on arrival of oil compatible hose for dredge unit. 0 yds processed; total = 122 yds washed; fresh water consumed = 0 BBLS. Hose came in for dredge, operational by 12:00. Had pre-job safety meeting. Took oil based fluids into unit, checking for leaks and making sure there is no possible escape of fluids. Began grinding operation at 13:00, everything mechanical worked fine. 1/2 screen on MTS shaker would not allow enough cut to get thru # 50 mesh shaker screens. 1/4" and 1/8" being hot-shotted from town. Worked dredge back and forth in pond to agitate fluids. Pulled MTS out to ready to install new screens. Welder continuing hopper project. Swaco unit down for inadequate MTS screen size. Grinding, process fluids. Replaced damaged electric line on dredge; operational at 11 :00 AM. Replaced 1/2" MTS screen with 1/4" screen (bad radius on 1/8" screen that was shipped). Took on fluid from dredge to slurry pit, had trouble controlling water volume. Add gel to viscosity until 60+ vis reached, circulate and grind to reach desired mud weight. Have to 'batch' mix at the moment to control water intake. Operation will smooth out and speed up with improvising and technique improvements. Dredge down from 0000 to 1100; damaged power cord. MTS mill down from 11 :00 to 12:30 due to grinding screen changes. 60 BBL slurry produced; water = 2 BBL per hour. continue processing fluids. Tried to get mud weight up, replaced the 1/4" screen with 1/8" to try to get a finer cut. Slurry tank arrived at 16:00, crane spotted it and pump skid in place. We rigged plumbing and electrical, pump #1 would not work. Replaced pump, worked bugs out of slurry tank to shaker loop, started processing at 23:00. Changeout screens on MTS mill = 1 hour. 90 BBL slurry produced; water = 20 BBLs used Processed fluid, adjusted rates of flow, churn additions to try to get weight higher. Rig up water line to slurry tank to flush suction. Inspect MTS blades. 130 BBL slurry produced; water = 5 BBL used Built 150 BBL 9.7Ib/55 vis slurry for total of 250 BBL injectable slurry. Began injection @ 11 :30 with 10 BBL water pre-flush, followed by 245 BBL slurry, chased with 300 BBL pit water lush. Ended injection @ 15: 11. Injection went smooth, pump performed as expected, no anomalies in pressures. Bring on more fluids to process. Service mud pump, and drive engine. Flush all lines. Bulk storage tank arrived at 16:00 spotted in berm, rig up to unit. Changed #1 shaker screens, put new #50 on. Shipped two (2) Halliburton valves to Bob Gaggon for use on Osprey, via Peak. 120 BBL slurry produced; 5 BBL water used. Processing fluid, need to fine tune dredge operation to get more 5/1/2003 3:20:42 PM 7/16/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 7/30/2002 00:00 - 00:00 24.00 Printed: prior to start of shift. Cleaned shaker screens on #1 shaker. Continued to process 10.4 wt slurry at a rate of 100 BBLS every 18 hrs. Performed maintenance on equipment daily. Cleaned and straightened containment area. Swaco mechanic came down and looked over Pacemaker pump, doing some adjustments and fixing minor tranny leak. Will begin rigging up Veco rod mill tomorrow. Each Swaco crew held JSA prior to start of shift. Veco hands arrived on location and were given job site orientation. Began rigging up Rod Mill. Got all their equipment set and bolted down. They will be back tomorrow with Millrite and Electrician. Swaco processed cuttings per normal. Bob worked over on various welding projects. Had 3" gun hose to Ghalleger develop pin hole, changed out. Processed about 220 BBLS of 10.5 wt. slurry. 5/1/2003 3:20:42 PM 7/29/2002 7/28/2002 7/27/2002 7/26/2002 7/25/2002 7/24/2002 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 ~ 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 24.00 24.00 consistent solids to fluid ratio to slurry tank. Plumb lines to bulk storage tank for 6x5x11 pump. Replacement water pump (2x1) got in, will plumb in as electrician wired it. Change out 3" ball valve to regrind pit (washed). Change out blades on MTS grinder, screen plugged with rubber. Change #1 shaker screens to #38. MTS mill down two (2) hours for blade change, rebuilt existing blade. 120 BBL slurry produced; 5 BBL water used. Trf 100 BBLS of 10.5 I 56 vis slurry to 100 BBL storage tank, build more slurry. Experimenting with screens, flow rates, chems to get more solids to drop through. Takes many circulations through MTS to get small amount of mtrl. Rig up bulk tank and pump. Rig up 2x1 water pump. Changed #2 shaker screens to 140 to help keep some of the fines, had to slow pump rate down to keep mud on the screen. Slower pump rate did not allow solids up the hose to the shaker. Got better results when piggy back #84 on top with #50 bottom of #2 shaker, could keep volume flow and got good solids over screens. Equipment down 1 hour for changing shaker screens and inspecting MTS blades. Process fluids. Current screening (#1 shaker = 50, @ 2 shaker = 84 top 50 bottom) and letting the slurry tank mix for 10 minutes before pumping to shaker seems to be the best method so far; still a lot of grinding taking place. Two (2) hour spill response meeting with Jason Crowell and Tim Johnson. Did unit maintenance, inspect MTS blades for wear (LOTO). Transferred 240 BBLS to bulk storage tank. Swaco crews held JSA before each tour. Continued to process material. Everything seems to be working fine. Have about 300 BBLS of slurry in holding tank. Current screening #1 shaker = 50 mesh, #2 shaker 84/50 mesh. Supervisor changeout today. Both Swaco crews held prejob safety meetings prior to start of shift. Transferred 10.3 ppg slurry to holding tank. Have about 500 BBLS of slurry at 10.3 and 50 vis. After making some processing changes and improvements we are obviously gaining ground on working smarter and more efficiently. Dredge is working fine. Changed out mill assembly on MTS. 14 worn blades causing mill to back off. Topped off conveyor gear box. Continue to process high quality slurry. Both Swaco crews held prejob safety meeting prior to start of shift. Continuing to process smart and efficient. Changed spider rubber in MTS-14 and inspected blades in same. OK. Performed injection #3 in late afternoon, 10.3 wt. and a 52 vis. Had a few minor problems but Well took fluid fine. Entire process is worked bugs out quickly. smoothing out nicely. Both Swaco crews held PSA 7/23/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) Printed: equipment. Each Swaco crew held pre-job safety meeting. Continue to process 10.5 wt slurry with our mill at a rate of about 175 BBLS a day. Changed out mill assembly to grind solids better. The process is working very well and I think we may have to move the dredge more often to continue getting high wt. slurry. Should inject #5 soon. 5/1/2003 3:20:42 PM 8/5/2002 8/4/2002 8/3/2002 8/2/2002 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 24.00 24.00 24.00 24.00 morning. PJSM w/each crew. Changeout day. Continue to RU Veco Ball Mill. CIGS cuttings hopper should be finished tomorrow. Built 2 manifolds to 50 bbl regrind tank. Transfer hi weight slurry to holding tanks. Removed gun line from injection pit to reinstall in regrind tank. Assembled spare rotating assembly for MTS-14 Swaco crews held JSA prior to start of shift. Plumbed in regrind tank and pump. Made up new hoses for system. Plumbed in 1" line for auger. Installed woods coupling on regrind pump. Continued to rig up Veco rod mill. Injected #4, everything went well. Got rod mill running and shipped regrind fluid to it. Found that discharge on mill was leaking bad and drum bolts were slinging mud. Shut same down and locked out. Removed snout piece and re-silliconed for another test run. Leaking even worse. Finally gave up around 12:30 AM and sent Veco home for sleep. Pulled gate and went to processing with our hammer mill. Will bring Veco back at daylight and try to fix leak. Swaco will continue to process material via our mill. Took 8 hours for the auger extension rig up. Each Swaco crew held JSA prior to start of shift. Still processing material thru our MTS-14. Continuing at a rate of about 180 BBLs per day. Veco crews worked on Rod mill all day trying to reseal discharge snout. Will let sealant set up overnight and try again in the morning. Checked out Pacemaker pump after injection and all is well. Performed daily maintenance on all Swaco gear nightly. Reassembled spare MTS-14 shaft. Did a little cleanup around unit. Have only used 10 sacks of gel since my arrival on July 20th. Will continue to process high quality slurry until we get the rod mill to stop leaking. Each Swaco crew held JSA. Continue to process high quality slurry with our hammer mill. Veco is still working on Rod mill. They tried welding up the discharge snout and turns out the drum is cast iron so the weld cracked out. Larry with Veco then took the end piece to town and said he would talk to his boss and come up with a new plan to keep it from leaking. In the meantime we will keep processing with our 8/1/2002 00:00 - 00:00 00:00 - 00:00 24.00 24.00 Each Swaco crew held JSA prior to start of shift. Crew change today. Continue to rig up Veco rod mill. Almost finished with CIGS cuttings hopper, will install tomorrow. Built two 3" manifolds for 50 BBL regrind tank. Transferred high wt. slurry to holding tanks. Removed Gun line from injection pit to reinstall in regrind tank. Assembled spare rotating assembly for MTS-14. Swaco crews held JSA prior to start of tour. Still processing high quality slurry. After moving dredge we have slowed a little on getting good cuttings, will move back towards rig and should be able to top off holding tanks and inject in the a.m. Performed daily maintenance on all equipment. Worked on finishing gun line manifold on regrind tank. Used crane to set regrind tank, hopper, auger extension, and scroll. Found that 125 kW Veco generator is under powered to start rod mill. Found 180 kW generator in Soldotna and it will be here first think in the 7/31/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ') 8/12/2002 8/11/2002 8/1 0/2002 8/9/2002 8/8/2002 8/7/2002 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: Each Swaco crew held JSA prior to start of shift. Continued processing high quality slurry. Changed out 90 and valve on 3" regrind system. Performed daily maintenance on all Swaco equipment. Veco came down with new and improved snout piece and carefully installed same. Will let cure overnite as per Veco request and then try again tomorrow. Swaco will inject #5 in the AM also. Each Swaco crew held JSA prior to start of shift. Crew change today. Injected #5 in the AM, 10.6 wt. Everything went well. Pacemaker pump is performing as required. Got Veco rod mill up and running around 10 AM. Kicking out 11 wt mud. Processed about 100 BBLS in an 8 hr period. Hands are adapting well to new addition. Dredge is still finding plenty of material to process. Have no idea how much is still in pit. PJSM for each crew. Drege down due to electrical problems. Rod mill transformer went down due to vibration @ 05:00. Switched to MTS-14 while waiting on electrician. Switch out transformer and back runnig @ 14:00 hrs. Changed screen on #2 shaker to 84 over 50. Plumb in 2" H20 line to enable flushing of slurry from tank to injection pump to prevent settling of solids in line during disposal periods. RU 2 500W lights for nighttime ops. Hook up vac hopper on skid and moved vac blower and shock tank further away to reduce noise levels on skid. All systems working well. Process pump quit and electricians fixed start contacts temporarily until parts arrive. Down time on dregde was 2 hours for remote control power problems Each crew held pre tower JSA meeting. Processed fluids, operation is running smoothly. Install new blade assy on MTS, redress old shaft. Change injection tank centrifugal pump housing (small washed). Transferred 100 BBL slurry to bulk storage (full). Transferred 100 BBL slurry to unit storage tank (full). Do all routine maintenance on equipment. Weld 3" dump line on vac hopper to discharge into process pit. Process pit centrifugal pump starter switch continues to over-heat (?) and kick pump off. Weld mounts for 500 W light stancions. Supervisors changed out. Each crew held pre tower JSA meeting. Performed injection #6, everything went well, pump performed as expected, no anomalies with well. Replaced flex rubber (Martin couplers) on regrind pump. Replaced entire coupler on bulk tank pump to a 3 lobe style, seem to get better service with the 3 lobe style coupler with these heavy fluids. Serviced all Swaco equipment and post injection maintenance on injection pump. Processed 240 BBL fluid thru rod mill, transferred to bulk storage. Mill still continues to leak at intake and Veco to come out 8/11/02 to try to alleviate problem. Each crew held a pre tower JSA. Processed fluids thru rod mill. Vacuumed out rod mill overflow containment every 90 minutes, splash guard has bad leak. Transformer on injection pit skid overheating, starter on injection pit centrifugal went out, had Electrician patch (safety) until we can get transformer and new starter out on Monday. Shut down rod mill to repair leaks, one rod end leaking badly, replaced rubber around intake. Repairs worked well. Will monitor closely. Rod mill down 2 hours to repair leaks. Each crew held a pre tower JSA. Crews helped recover sunken dredge hose. Crews performed daily maintenance on rod mill and Swaco unit. Performed injection #7 with Schlumberger running a temperature log. Injection went smooth, no glitches, ran extra 100 BBL post flush to see 5/1/2003 3:20:42 PM 8/6/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) Printed: injection pump, put additional oil pressure gauge on gear end oiler, replaced other oiler gauge, serviced drive motor. Injection pump/ motor has approximately 67 hours on them (6739 BBL pumped @ average of 5/1/2003 3:20:42 PM 8/16/2002 00:00 00:00 24.00 Each crew held a pre tower JSA. Night crew performed daily maintenance on Swaco equipment. Performed injection #6. Adjusted gear and oil pressure to 90 psi by the end of injection; when gear and pump temp was approx 100 degrees, pressure would drop to 45+ psi. While injecting bottom half from bulk tank, started to lose prime. Back flushed lines would work fine for a few BBL then prime pressure would start to drop off again. Finally ended up transferring all fluids from bulk storage to injection pit and storage tank so we could continue injecting. After injection was complete, tore down transfer pump and lines impacted and tested same, and ascertained problem is inside tank of suction. MTS drive motor shorted out inside, swapped rod mill pump motor in its stead, shimmed and aligned motor to shaft dead on, runs perfectly. One (1) hour total down time for bulk storage transfer pump. Four (4) hours down time changing out MTS drive motor. Each crew held a pre tower JSA. Process slurry thru MTS, dredge struggling to find adequate material, will move dredge. All Swaco systems running fine. Crews shut down shakers when possible, inspected and cleaned screens, tensioners, etc. (no down time). Cleaned in and around unit. Performed post injection service on 8/15/2002 8/14/2002 8/13/2002 00:00 00:00 - 00:00 00:00 - 00:00 00:00 24.00 24.00 24.00 if we could get a better log. Pump performed well. Big G Electric came out and replaced starter for injection centrifugal, transformer on injection pump skid. Installed some halogen lights around unit, visibility much better. Veco came out and inspected rod mill and will get replacement drive shaft bearings. GLM came out and realigned drive to drum on the rod mill, seemed to quiet it some and decrease vibraion. Problem won't be totally fixed until bearings are replaced. Rod mill down 4 hours for Veco inspection and GLM work, did not affect processing or injection. Each crew held a pre tower JSA. Process material thru rod mill until 12:00, shut down mill so Veco could remove drive shaft & take to Kenai to machine shaft and install new bearings. Should be back in operation by Friday, 8/16, at latest. Dredge down for four (4) hours hose blocked, electric line kinked, turned dredge around in pit to get more material. Night crew serviced all Swaco equipment. Process fluid thru MTS. Dredge is having trouble getting fluid to slurry tank. Rod mill down for repairs by Veco for approximately three (3) days. Dredge down for approximately four (4) hours due to low output. Each crew held a pre tower JSA. Process fluid thru MTS. Changed out 4" butterfly valve and back vac'd obstruction in jet and fill lines on slurry tank. Electrician installed new transformer for rod mill, added lights and outlets around unit, night time visibility much improved. Replaced 3" hose on Galligher pit gun line. Replaced coupling and spider on MTS, realigned to reduce wear, will keep an eye on it. Replaced bulk tank transfer pump, front bearings and mechanical seal out. Increased gear end oil pressure on injection pump and ordered back-up gauges for it. Dredge lost auger drive cable for four (4) hours. Crews performed service and maintenance on unit. Change out day for crews. MTS mill down two (2) hours for drive coupling hub change and realignment of motor to mill. Dredge down for four (4) hours with auger hoist cable broken. 8/12/2002 00:00 - 00:00 24.00 Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date End: Group ) ) 8/30/2001 Printed: 5/1/2003 3:20:42 PM 8/22/2002 00:00 - 00:00 24.00 down changing out #1 shaker screens. Each crew held pre tower JSA. Performed injection #11; during post flush pump developed unusual noise, determined it was coming from gear end. Shut down 15 minutes while we inspected pump, continued to inject at one (1) BPM and closely monitored gear end oil pressure and bearing temp. After 45 minutes no change in temp or pressure, resumed two (2) BPM rate. Rest of injection went fine. Went through fluid end of pump after injection, found small piece of rubber in suction, torqued pistons; sand settling in suction chamber due to too large of screen on OBM pit transfer pump. Fixed splash guard on rod mill, processed thru MTS in the mean time. Veco/GLM installed drive shaft with new bearings on rod mill, adjusted and tested. Seems to run as expected. Replumbed suction on bulk tank to reestablish good suction, not much difference, will try larger suction line. Processing fluids thru rod mill at a fast rate. Injection pump down 15 minutes for mechanical inspection. Each crew held pre tower JSA. Swaco equipment running fine. Processed material thru rod mill. All Dredge went down @ 12:30 to 18:00 8/21/2002 8/20/2002 8/19/2002 8/18/2002 8/17/2002 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 24.00 00 BBL per hour). Modified MTS skid to better accommodate new motor, added serviceable '0' ring and containment band. Rigged up 4" hard line for vac system to eliminate trip hazards with hoses on ground. Crews performed routine maintenance and inspection. Each crew held a pre tower JSA. Processed material thru MTS. Delivered old MTS drive motor to Superior Electric, picked up new motor at OSK dock (from Bruce). Installed motor on rod mill regrind pump. Filled bulk tank. Crews performed service maintenance and inspection on Swaco equipment. Pulled valve caps off injection pump, inspected valves and seats in preparation for large injection. Everything running smoothly. Each crew held a pre tower JSA. Performed injection #9, with the exception of attempting to inject majority of water from OBM pit, pumping fluid over shakers, injection is going fine. Shut down operation at the 1500 BBL point and serviced pump and drive engine and changed out suction valves as precautionary measure as seats and valves were starting to show wear. Crews inspected MTS blades and coupling; good condition. Replaced broken spring on #2 shaker, inspected screens. Welder installed jet nozzle near bulk tank suction to help with solids control. Crews performed routine maintenance on all Swaco equipment. Inection pump down 1.5 hours for suction valve change and maintenance. Each crew held a pre tower JSA. Continued injecting excess water from OBM pit. Stopped injection at 1800 after a total disposal of 4,533 BBL water. Injection went smoothly, will need to go through pump and service drive motor. Began processing fluids through MTS at 1800 hours. Crews performed routine and preventative maintenance on Swaco equipment. Shutdown injection operation from 0900 to 1000 to service and inspect pump and drive engine. Each crew held a pre tower JSA. Process fluids through MTS. Changed out screens on #1 shaker, from 38 to 50, #38 top screen skin worn off in spots. Serviced and inspected injection pump and drive engine. Changed out discharge valves, drained and changed oil in rod oiler, topped off all fluid levels. Installed flush line on MTS mill. Electrician wired electric motor on rod mill regrind pump. One (1) hour 8/16/2002 00:00 - 00:00 24.00 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ~iìl~~gl e u ) ~I r ) 8/27/2002 8/26/2002 8/25/2002 8/24/2002 8/23/2002 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 00:00 00:00 24.00 24.00 24.00 24.00 24.00 Printed: with impeller jamming and pump bearing service. Swaco crews serviced and did repairs to unit. Moved bulk tank transfer pump closer to tank suction to try to shorten suction run. Changed crankcase oil and filter in Detroit engine. Installed new pinch valves on injection pump rod oilers. Rig up line to 100 BBL tank to take on water for injection post flush thru injection pit pump and 'Y' strainer. Checked rod mill pillow block bolts for tighness. Repaired small wash out in process pit gun line manifold. Intake on rod mill leaking again even after our repair, will have Veco come fix it. Dredge down from 12:30 to 18:00; impeller jammed, bearing service. Swaco process pit down 30 minutes for wash out repair. Each Swaco crew held pre tour safety meeting. Continuing to process slurry thru rod mill at a 300 BBL per day rate. Shut down rod mill and helped Veco repair feed line to stop leaking. Continued to process thru our MTS-14 until Rod mill is operational. Got Rod mill up and running at 9:00 p.m. Leaks very little now. I think it is much more manageable. Supervisor changeout today. Injected #12 this morning, everything went well except charge pump is still losing prime on the 450 BBL bulk tank. I found that the mac-pac has been leaking so we will change out tomorrow and test on next injection. Veco Rod mill down for 6 hours to fix leak. Continued to process with Swaco mill in the interim. Each Swaco crew held JSA prior to start of shift. Continued to process high quality slurry with Rod mill. Was hoping for another injection today but after changing direction of dredge, Operator had a hard time orienting himself to find good material. About 75 BBLs short at 7:00 p.m. Will inject in the a.m. Changed out stuffing box, mac-pac and impeller on bulk tank charge pump. I found that the packing has been leaking and there was a grinding impeller installed that, of course, causes cavitation by design. I think this will fix our suction loss during injection. Fabricated and installed a float type sight gauge for regrind tank to prevent any guess work on levels of same. Serviced Pacemaker and prepared for upcoming injection #1. Each Swaco crew held JSA prior to start of shift. Continued to process material thru Rod mill. Performed housecleaning and serviced equipment including Rod mill. Injected #13 and everything went well. Fixed the bulk tank charge pump from cavitating. Changed out screens on the scalper shaker to 140/50 to attempt to trap more of the fines that we are currently pumping back to reserve pit. Took apart slurry tank manifold and used vac to unclog three jet lines that were packed off. Each Swaco crew held JSA prior to start of shift. Processed material thru rod mill. Lubricated rod mill drive gear and conveyers. Checked oil in auger conveyer. Replaced leaking liner bolt gasket on mill drum. Serviced all Swaco equipment. Changed out gear end of Pacemaker to ep320 gear oil and cleaned sump screens. Removed #1 jet nozzle on slurry tank to prevent pack off. Added a piece of chain link fence onto dredge suction pipe to catch troublesome debris. Shaker screen inventory is as follows: 3 boxes-50 mesh, 1 box-84v, 2 boxes-30 mesh, 1 box-175 mesh, 1 box-210 mesh. Each Swaco crew had pre-job safety meeting prior to start of shift. Processing thru rod mill. Replaced gasket on leaking liner bolt. Performed daily maintenance on all equipment. Rigged up wash-down line to wash down pit walls during injection. Will inject approximately 4500 BBLs out of reserve pit tomorrow. Bolt broke on rod mill case and 5/1/2003 3:20:42 PM 8/22/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 9/4/2002 9/3/2002 9/2/2002 9/1/2002 8/31/2002 8/30/2002 8/28/2002 8/29/2002 00:00 00:00 - 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: welded up plate to cover hole. Couldn't restart regrind pump; believe it is a starter problem. Will have electrician take a look tomorrow. Processing with MTS-14 thru the night. Each Swaco crew held JSA prior to start of shift. Processed material thru MTS-14 because of fried regrind pump motor. Began injection #14. Will inject 500+ BBLS of high wt. slurry followed by about 4000 BBLS of 9# slurry direct from reserve pit. Changed scalper shaker to 84 mesh on both decks. Changed motor out on regrind skid to put rod mill back on line. Continue to process cuttings during 38 hour injection. Each Swaco crew held JSA prior to start of shift. Continued to process slurry during injection #14 which lasted 40 hrs. Drained and cleaned solids buildup out of injection ply. Rewired and installed new motor on bulk tank charge skid. Will begin washing cuttings towards center of oil base pit. Continue to grind cuttings in OBM pit. Each Swaco crew held JSA prior to start of shift. Continued processing material. Completed injection #14 and stopped to service injection equipment. Will fire up on water injection this afternoon after IISCO finishes working on double pin recorder. Serviced all equipment as per normal. Continuing to process high quality slurry. Tightened bolts on rod mill. Cleaned connex and stocked freight. Each Swaco crew held JSA prior to start of shift. Continued processing thru rod mill. Will have to shut down soon and fix some leaking drum and cap bolts. Repaired hole in 6" dredge hose and took out 100' of hose to help cuttings to slurry tank. Performed daily maintenance on all equipment. Continued then finished injection #15; shut it down due to loss of prime on small water pump feeding injection. Will solve suction problem and resume tomorrow. Will open up fluid end of Pacemaker and inspect due to high # of hours before next injection. Shut down rod mill @ 9:00 p.m. due to leaks and switched to MTS-14 for processing. Vacuumed out containment on rod mill. Rigged up 50' suction hose on little H20 pump and tested - good. Each Swaco crew held JSA prior to start of shift. Topped off 400 BBL slurry holding tank with 10.5 material. Repaired all leaks on rod mill and got it up and running. Cleaned up all containment areas and performed daily maintenance on equipment. Went thru Pacemaker and replaced discharge valves. Seats and entire suction looks good. Injected #10 and pumped 616 BBLs down before Ray Springer told us to suspend all operations until further notice. Had hands scrubbing and maintenance in the interim. Each Swaco crew held JSA prior to start of shift. General housekeeping was performed. Changed out mission pump on bulk tank charge. Injected #17; went well. Repaired hose on dredge. Continued processing on OBM pit. Most of the water is out of water base pit. Dredge down 8 hours for repair. Each Swaco crew held JSA prior to start of shift. Performed daily maintenance on all equipment. Continued to process slurry. Turned dredge around at 1800 hours and are still getting good material. Checked in supplies. Tightened bolt on Rod mill that was leaking. Added 5 gallons used motor oil in SAA drum following oil change. Each Swaco crew held JSA prior to start of shift. Performed injection #18; went well. Began processing thru Rod mill and building high quality slurry at a high rate. Since turning dredge around, we are getting a lot of material. Process is running fine. Stopped for a few 5/1/2003 3:20:42 PM 8/27/2002 00:00 - 00:00 24.00 Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: HANSEN #1 HANSEN #1 ROT - DRILLING Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ') ') Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 9/4/2002 00:00 - 00:00 24.00 9/5/2002 00:00 - 00:00 24.00 9/6/2002 00:00 - 00:00 24.00 9/7/2002 00:00 - 00:00 24.00 9/8/2002 00:00 - 00:00 24.00 9/9/2002 00:00 - 00:00 24.00 9/1 0/2002 00:00 - 00:00 24.00 9/11/2002 00:00 - 00:00 24.00 9/12/2002 00:00 - 00:00 24.00 Printed: 5/1/2003 3:20:42 PM minutes in late afternoon to tighten mill bolts again to stop leaking. Checked fluid levels on Pacemaker pump to prepare for upcoming injection. Each Swaco crew held JSA prior to start of shift. Continued to process material thru Rod Mill. Serviced all equipment nightly. Stopped Rod Mill and serviced after tightening leaking bolt. Tore into Pacemaker and changed out all packing, plungers, and one suction valve and seat and checked discharge valves and seats for wear. Installed 1/4" plugs in bottom of packing glands. Each crew held a pre tower JSA. Performed injection #19. Changed bowl, impeller, wash plate, and mech seal on #1 slurry centrifugal. Changed out #2 shaker knife valve. Crews did daily service and maintenance. Welded 4" nipple on #2 shaker dump trough to facilitate dump line to galagher pit. Quality crew change oil in both gen sets; made repairs to exhaust system on generator P-0303. Supervisor crew change. Equipment down 2 hours for maintenance work on unit and oil changes on gen sets. Each crew held pre tower JSA. Process slurry thru Rod mill; getting low on heavy material. Crews performed daily maintenance on equipment, post injection pump inspection and service. Plumb lines to prepare to vacuum slurry tank. Each crew held a pre tower JSA. Move vac unit and surge tank to back side of unit and rig up to slurry tank in preparation for vacuuming remainder of OBM pit. Perform injection #20; used dredge to pump as much material as it could until it could no longer pump. Crews performed routine maintenance. Welded support brace on middle gun line in process pit, built vac wands and handles. Each crew held a pre tower JSA. Performed routine maintenance on unit, inspected all pumps, lines and hoses for wear. Installed new wear sleeves on slurry tank #1 centrifugal. Rigged up vac lines out to pit, got suction hoses, valves, wands, etc. rigged up. Quality crews power washed dredge and related equipment, and moved same to WBM pit. Swaco and Quality crews began to vac remainder of OBM pit. Dredge down 8 hours for OBM to WBM pit change. Each crew held pre tower JSA. Rig up to process from WBM pit, and to vac from OBM pit. Rig down operation from OBM pit and work WBM pit and process washed cuttings from gravel wash. Attempt to process. Equipment down while rigging dredge to slurry tank, clean rocks out of slurry tank centrifugals. Each crew held a pre tower JSA. Processing fluid from WBM pit adding washed gravel via vac system. Crew packed off hopper and backed slurry in to shock tank. Unpacked everything, cleaned gravel out of shock tank and vac system. Rerouted hoses to use 25 BBL tote; act as shock tank re-established vac system. Changed #2 shaker screens to #38 to use as a grinding loop via 4" dump back to Galagher. Changed #1 shaker screens to #84 to act as scalper. Began processing gravel at 16:00, coordinating vac flow (water to gravel ratio) with Quality crews to the needs for material for the Swaco unit. Bob Crawford was using a utility knife to cut 4" vac hose, knife slipped and he stabbed himself in the leg; wound required three (3) stitches at hospital. He was released to return to work. Vac system equipment down for six (6) hours for cleaning and repair. Each crew held a pre tower JSA. Processing gravel via vac system. Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) 9/19/2002 9/18/2002 9/16/2002 9/14/2002 9/13/2002 9/17/2002 9/15/2002 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: Replaced swivel nipple on Galagher pit gun line. Did daily service on all Swaco equiment; shut down mill to clean and service (.5 hour). General housekeeping and clean up around unit. Everything running smoothly and as it should. Each crew held a pre tower JSA. Continued to process gravel via vac system. Performed routine maintenance on Swaco equipment. Started injection #21 at 10:00 AM; could not establish prime. Tore pump fluid end down and found coal in suction and discharge valves; cleaned out and was able to prime, tested lines to 2000 psi. Began with slurry and encountered same problem with coal in system. Shut down slurry injection, tore fluid end down and cleaned out pump; flushed all lines with fresh water and began post flush. Finished post flush at 18:00, transferred slurry from injection tank to upright slurry tank to store, cleaned injection tank. Ran all mud bck over shakers to injection tank and buit volume. Tested integrity of all valves in system. Replaced hanger bearing on auger in front of #2 shaker. Process fluids. Swaco unit down from 11 :00 to 23:00 due to gravel contamination in pit system. Each crew held pre tower JSA. Finish processing washed gravel. Began injection #22 at 14:00; all slurry injected by 16:00. We then continued injecting water from the WBM pit from slurry tank over #84 shaker screens. Crews performed routine maintenance on all Swaco equipment. Each crew held a pre tower JSA. Continued to inject fluid from WBM pit. Crews did routine maintenance on all Swaco equipment, scrubbing, and vacuuming in and around unit. Miscellaneous repairs on equipment. Prepare to process remainder of fluids from OBM pit. Each crew held a pre tower JSA. Continue to inject fluid from WBM pit. Changed all three (3) fluid end rod packing in injection pump. Service pump, add three (3) gallons oil to gear end, add one (1) gallon motor oil to engine. Changed oil in process pit agitator. Scrub and clean unit, and rod mill. Each crew held a pre tower JSA. Concluded injection #22 at 10:30. Broke down injection line to allow vac truck access to OBM pit, rig up. Rig up vac truck to pump excess water off OBM pit to begin processing remainder of OBM. Began injection #23 at 15:30. Swaco crews performed routine maintenance on equipment. Each crew held pre tower JSA. Finished injection #23, day 2 @ 8:15. Serviced injection pump and engine; will need mechanic down to check engine out (oil drips and adjustments). Added 2 gal gear oil to inj pump, 1.5 gal motor oil to engine. Began processing taking on fluid from vac truck, approximately 40 minutes per load. Used Swaco vac system to keep slurry tank at an even pace with transfer to shakers. Crews performed routine maintenance on Swaco equipment. No down time. Each Swaco crew held JSA prior to start of shift. Changed out all 3" hoses on Dominater to 4; works much better. Processed material thru Rod mill. Worked on Rod mill to fix leaks. Drained slurry tank and inspected pump #1. Ordered Vortex assembly to stop pack off with large rocks. Serviced Pacemaker to prepare for injection. Supervisors changed out in the AM. Injected #25; everything went well. Continuing to use vac truck to clean OBM pit. Rod mill down for three (3) hours to tighten bolts. 5/1/2003 3:20:42 PM 9/12/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) 9/28/2002 9/27/2002 9/26/2002 9/25/2002 9/24/2002 9/23/2002 9/22/2002 9/21/2002 00:00 00:00 - 00:00 00:00 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 00:00 00:00 00:00 - 00:00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 Printed: Each Swaco crew held JSA prior to start of shift. Continuing to process material via dominator to shakers. Working on Swaco slurry tank. Installed Vortex system on #1 slurry pump. Cleaned jet lines out. Sucked out slurry tank and received new belts for drive. Dragged 4" hose from slurry tank discharge to shaker riser to flowline. Waiting on 10" pulleys for Vortex pump. Serviced Rod mill, entire gel unit and Pacemaker pump. Pulled suction and discharge caps and inspected valves and seats. Tightened belts on Rod mill. Injected #26 and everything went well. Well pressures are good; it is taking fluid fine. Disposed of three (3) gallons of used rod oil in the SAA site. Each Swaco crew held JSA prior to start of shift. Changed out two 4" butterfly valves on slurry tank. Hooked up hoses and lines to use slurry tank for vacuum. Fixed leak on Rod mill and serviced same. Installed new belts on both slurry pumps and tested. Injected #27 and everything went well. Tested slurry tank and vacuum; vacuum worked well but slurry tank suction packed off with rocks due to faulty suction valve. Cleared material from same and got up and running. Each Swaco crew held JSA prior to start of shift. Still processing material via Swaco vacuum and Peak Dominator. Process will begin to slow now due to harder to reach cuttings dispersed throughout pit. Had to use some of our vac hose from slurry tank to reach far end of pit with vac truck. Injected #28 and it went well. Should be able to close out OBM pit by Tuesday or Wednesday. Serviced all equipment. Each Swaco crew held JSA prior to start of shift. Released Peak vac truck and went back to using our vac system once replacement gen-set arrived. Performed daily maintenance on all equipment. Continuing to process large rocks and heavy material from bottom of pit. Each Swaco crew held JSA prior to start of shift. Continued processing material thru Rod mill. Slurry tank packed off due to high water content. Unclogged all lines and got up and running. Re-routed vac system to hopper first, then slurry tank. Injected 1000 BBLs of rain-water collected in OBM pit from rainfall over the last 38 hours. Each Swaco crew held JSA prior to start of shift. Processed material thru vac and Rod mill. Dewatered containment after heavy rains. Cleared valves on slurry tank. Serviced all equipment nightly. Injected #30 and everything went well. Repaired PVC and a few hoses to improve vac system. Repaired regrind discharge hose. Inspected Gallager pump suction and unplugged gun line. Each Swaco crew held JSA prior to start of tour. Processing the last of the material from OBM pit. Serviced all equipment nightly. Drove to Ninilchik and picked up 3 BBL hopper from Devon to be set up on the digs. Each Swaco crew held JSA prior to start of shift. All Hansen personnel broke to daylight hours only today. Finished OBM pit today at 10:00 AM. Injected #31 and everything went well. Flushed pits and circulated WBM water throughout pits and shakers and flushed injection of slurry with same. Hotsy off #1 shaker until spotless. Hotsy part of upper deck. Used hotsy to clean all vac hoses in reserve pit. Washed out Rod mill and shut down. Will use MTS-14 if any more grinding occurs. After injection was complete, we filled all tanks partial full with WBM water and will agitate same overnight. Will start tank cleaning in the morning. Each Swaco crew held JSA prior to start of shift. Spent day tank 5/1/2003 3:20:42 PM 9/20/2002 00:00 - 00:00 24.00 Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date: 8/30/2001 End: Group: ) ) ) Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - DRILLING Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 9/28/2002 00:00 - 00:00 24.00 9/29/2002 00:00 - 00:00 24.00 9/30/2002 00:00 - 00:00 24.00 0/1/2002 00:00 - 00:00 24.00 Printed: cleaning. Hotsyoff Rod mill and skid and containment. Rigged down conveyor extension and flight. Rigged down flow line to Rod mill. Rigged down 6x5 bulk tank chg and rigged off lines to bulk tank. Opened up access hatch to prepare for tank cleaning. Vac out OBM pit one last time due to melting ice-flow. Injected #32 and everything went well. Each Swaco crew held JSA prior to start of shift. Used Hotsy to clean and close out 100 BBl Swaco tank, 90 BBl slurry tank and pump skid, regrind tank and pump. Vacuumed out containments and started loading trucks. Built high viscosity fluid in injection pit and established grinding loop to classify fluid. Each Swaco crew held JSA prior to start of shift. Cleaned and close out 400 BBl Rain for rent bulk tank. Pulled rods from Veco rod mill. loaded slurry tank, BEM shaker, slurry tank pump skid, regrind tank onto trucks. Cleaned Swaco process pit and sucked out Gallager pit to 25 BBl tote. Started cleaning containments. Worked on logistics for load out. Injection 33 went downhole in early evening. Each Swaco crew held JSA prior to start of shift. Injected #34, last injection, and pumped 7 BBls of diesel to freeze protect. Broke down and cleaned all containments. loaded out trucks. Rigged down and shipped out Veco Rod mill. Cleaned all pits after injection and ended up with 8 BBls of sand into 25 BBl tote. Used all gel on location and worked well. Went through pump parts in connex. Set Swaco hopper and it worked well. 5/1/2003 3:20:42 PM Start: Rig Release: Rig Number: 273 8/30/2001 Spud Date End: Group: 8/30/2001 ) Printed: 5/1/2003 2:15:37 PM 7:30 - 20:30 3.00 WELCTL OTHR RIG UP Rig up test equipment. Continue mixing OBM & R/U Op's. operations. PJSM, Transfer 368 bbls OBM from pits rigging up operations. Pull BPV with FMC. Continue mixing OBM & R/U op's. Rig up SWS equipment & run Temperature Log. Start in hole @ 1530 hrs. Log from 4850' to 6000'. POOH with wireline. Out with tools @ 1700 hrs. Rig down SWS equipment. Continue mixing OBM & R/U op's. 3:30 4:00 4:00 7:30 0.50 ABANDr-.. OTHR RIGUP 3.50 ABANDr-.. SURV RIG UP 2:30 14:00 00:00 10:30 3:30 00:00 0:30 2:30 .00 ABANDr-.. RURD RIGUP 0.00 ABANDr-.. RURD RIGUP 0.50 ABANDr-.. RURD RIGUP 2.00 ABANDr-.. RURD RIGUP 3/18/2003 00:00 0:00 0:00 14:00 0.00 ABANDr-.. RURD RIG UP 4.00 ABANDr-.. SFTY RIGUP 3/17/2003 3/16/2003 00:00 - 00:00 24.00 ABANDr-.. RURD RIGUP Spot 2- 500 bbl return tanks in containment, build containment for tubing lay down, clean pits, rcv'd 560 bbls base oil to upright tanks, Test and run #1 pump, blow dn lines, clean trip tank, test and run#2 pump, blow dn and rig dn test line. clean and prep pits for oil base mud, blow dn mud pump suction lines, charge pumps, air purged top drive control panel, installed screens on mud cleaner, RU 2" blow dn hose from rig floor, installed derrick heater, RU pre-mix tank, changed out 2-8: valves in pill pit. Inspect and prep pits for taking on mapco pjsm,Take on mapco (base oil) for mud, Pump thru gun lines and hopper lines check for leaks, OK batch mix oil base mud, rcv'd another 543 bbls mapco and put into uprights. mixing 2nd batch of OBM Spill drill wi CISPRI, both crews and rstbt crew, deploy fast tank and mop skimmer. Transfer batch #2 OBM to pits, Mix batch #3. Continue to mix Batch #3 OBM. Continue with rigging up operations. Circulate & blend all mud in pit system. Continue with rigging up to tank farm. Continue with 3/15/2003 3/14/2003 3/12/2003 3/13/2003 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 24.00 ABANDr-.. RURD RIGUP 24.00 ABANDr\ RURD RIGUP 24.00 ABANDr\ RURD RIGUP 24.00 ABANDr\ RURD RIGUP RU Top Drive, Steam out base oil containment to spot 2 ea 400bbl uprights from Attigun. mud shack on loc. Dismantel old G&I containment. Thaw cuttings tanks. 2 contract electricians finish wiring Swaco. Dismantel old drum storage alongside rig. Nabors work on top drive, spot catwalk and slide. thaw berms around rig. trouble shoot camp generator High winds, slow progress, re-set plywood bottom and set 2 -400bbl uprights in containment. set stairs, start diplscement tank berm. thaw berms with steamer and rig. mud loggers shack on location, mud engineers shack on location, 2 CISPRI techs rig orientation for 2 hrs. Set back pressure valve. Nipple down tree, PU single gate & mud cross, blow dn choke manifold. Cleaning pits. spot mud shack, set EPOCH shack, set mud cross, double gat and hydril, set spacer spool,RU bell nipple, function trip tank valve,install turnbuckle cables, line up to test mud pumps. clean pits Adjust turn buckles to center stack over hole, hook up hydraulic lines to BOP stack,hook up choke line to mud cross and tighten, hook up flowline, install drip pan under rotary table, take stack measurements, install 3-112" rams in BOP, top and bottom, install blinds in the middle, tighten ram doors, hook up hydraulic lines and hydril.set cuttings tank and pre-mix tank wi hopper. run 2" hose from trip tank pump to flow line riser for hole fill. MU xo flange on stack for kill line. RU 2" jumper hose from Stand pipe to flow line for function and operational test on mud pumps, PJSM-function test on #2 pump. CISPRI spill conex and trailer on location. Swaco working on FCO, build wind walls on G&I. remove last of ice. 3/11/2003 00:00 - 00:00 24.00 ABANDr-.. RURD RIGUP Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: ) 18:00 18:30 19:00 20:30 8:30 9:00 20:30 22:00 0.50 0.50 .50 .50 WELLSR TRIP DECaMP WELLSR EaRP DECaMP WELLSR PLGM DECaMP WELLSR CIRC DECaMP Printed: Circ to pits @ pits. RID lines. P/U 5-1/2" DP to 16450'. M/U Top Drive. Align Top Drive to hole, Adjust rail & Torque Tube. Tag Plug @ 16466' Attempt to catch plug w/ no success. Circ Bttms up, monitor well (static). Pump Dry job (small). 5/1/2003 2:15:37 PM 6:30 14:30 - 00:00 00:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 2:00 - 13:00 3:00 - 16:30 3/22/2003 3/21/2003 3/20/2003 8:00 .50 9.50 0.00 0.50 0.50 1.00 1.00 3.50 12:00 3:30 14:00 16:00 17:30 18:00 19:00 23:00 00:00 11:30 WELLSR CIRC WELLSR TRIP DECOMP WELLSR TRIP DECaMP WELLSR CIRC DECaMP WELLSR SFTY DECaMP WELLSR CIRC DECaMP WELLSR EaRP DECaMP WELLSR CIRC DECaMP 03:30 00:00 - 03:30 15:00 - 00:00 DECaMP 13:30 14:30 16:00 17:30 18:00 19:00 23:00 00:00 12:00 11 :30 14:00 .50 .00 2.00 1.50 0.50 1.00 4.00 1.00 2.00 9.00 2.50 8.00 3.50 WELLSR TRIP DECaMP WELLSR OTHR DECaMP WELLSR RURD DECaMP WELLSR RURD DECaMP WELCTL BOPE DECaMP WELLSR RURD DECaMP WELLSR TRIP DECaMP WELLSR TRIP DECaMP WELLSR TRIP DECaMP DECaMP WELCTL BOPE DECaMP WELCTL EaRP DECaMP WELLSR PULD WELLSR PULD DECaMP Pull tubing to floor & lay down tubing hanger, XO's & pup joints. Monitor well. POOH, UD tubing. Clean joints & vacuum out excess fluid before laying down each joint. UD 3-1/2" Tubing. Vacuum out excess fluid from tubing prior to lay down joint. Rig down Tuibng equipment. Change out bails clear floor. Rig up test joint & set test plug. Change out top to f/3-1/2" to 5-1/2", Bottom rams 3-1/2" to 2-7/8" x 5-1/2" VBR. Install VBR's upside down, pull same & turn over. Test Rams to 250 psi & 5000 psi. Rig down test equipment & set wear bushing. Rig up floor for picking up 5-1/2" DP & BHA. Rig up Weatherford lay down machine. Test floor safey valves to 250 psi & 5000 psi. Rig up Tongs to make up DC's Change out elevators & P/U BHA. RIH, P/U 5-1/2" DP. Drift & strap w/ picking up DP. P/U 5-1/2" DP. Strap caliper & rabbit pipe while picking up same. (196 joint P/U @ 1200 hrs) P/U 5-1/2" DP. Strap caliper & rabbit pipe while picking up same. Re-rig Weatherford lay down machine to prevent line from chafing. (operators request) P/U 5-1/2" DP. Strap caliper & rabbit pipe while picking up same. P/U 5-1/2" DP. Rabbit & strap pipe. Rig up to displace hole. Hold PJSM on displacing well w/ OBM. with Rig Team. Ship fluid across surface system, Swaco shaker screens blinding off. Change out Swaco screens, ship fluid across system OK. Pump 80 bbls spacer & Displace well with 8.6 ppg OBM. Take diesel/crude returns to tank farm & G&I. 90 spm w/ 2000 psi, balnce mud weight. Check shakers, 3/19/2003 14:30 05:00 07:00 08:00 11:30 12:00 13:00 23:30 - 00:00 00:00 - 05:00 5:00 07:00 08:00 11:30 12:00 13:00 14:30 0.50 2.00 1.00 3.50 0.50 .00 .50 0.50 5.00 WELLSR PULD WELLSR OTHR DECaMP WELLSR RURD DECaMP WELLSR OTHR DECaMP WELLSR RURD DECaMP WELLSR SFTY DECOMP WELLSR RURD DECaMP RIGMNT RGRP RIGUP WELCTL BOPE DECaMP DECaMP Test BOPE; Top pipe rams, Floor safety valve, manual kill line valves, choke manifold valves 7,11,6,4,10,2,3,9 to 250 psi & 5000 psi. Test pump failed while testing valves 1 & 8. Repair rig test pump. Continue testing BOPE, Finish testing choke manifold valves, Manual choke line valve, HCR, Lower Pipe rams, Blind rams, Upper & Lower IBOP's to 250 psi & 5000 psi. Test Hydril to 250 psi & 3500 psi. Perform accumulator test. Tested flow line alarms, Hi & Low level pit volume alarms, trip tank, Methane & H2S gas detectors & alarms. Test witnessed by AOGCC Rep. Jeff Jones. Rig down test equipment Attempt to screw into to tubing hanger & recover test XO. Rig up to pull tubing. Change out 500 ton to 350 ton bails wait on same. Screw into hanger with landing joint, BOLDS. Hold pre-spud with Company reps, Toolpusher & Rig team members. Finish rigging up equipment to lay down & clean out tubing. 3/18/2003 20:30 - 23:30 3.00 WELCTL BOPE RIGUP Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 3/6/2003 Group: Spud Date: 8/30/2001 End: ') Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 3/22/2003 22:00 - 00:00 2.00 WELLSR EaRP DECaMP 3/23/2003 00:00 - 15:30 15.50 WELLSR TRIP DECaMP 15:30 - 16:00 0.50 WELLSR EQRP DECaMP 16:00 - 17:30 1.50 WELLSR TRIP DECaMP 17:30 - 19:30 2.00 WELLSR OTHR DECaMP 19:30 - 00:00 4.50 WELLSR EQRP DECaMP 3/24/2003 00:00 - 04:00 4.00 WAlTON EOI P DECaMP 04:00 - 13:30 9.50 WELLSR TRIP DECaMP 13:30 - 14:00 0.50 WELLSR WASH DECaMP 14:00 - 17:00 3.00 WELLSR MILL DECaMP 17:00 - 18:30 1.50 WELLSR CIRC DECaMP 18:30 - 00:00 5.50 WELLSR TRIP DECaMP 3/25/2003 00:00 - 04:00 4.00 WELLSR TRIP DECaMP 04:00 - 06:30 2.50 WELLSR PULD DECOMP 06:30 - 07:30 1.00 WELLSR OTHR DECaMP 07:30 - 11 :00 3.50 WELLSR PULD DECaMP 11 :00 - 12:00 1.00 WELLSR TRIP DECaMP 12:00 - 13:00 1.00 WELLSR OTHR DECaMP 13:00 - 16:00 3.00 WELLSR TRIP DECaMP 16:00 - 17:00 1.00 WELLSR OTHR DECaMP 17:00 - 20:30 3.50 WELLSR OTHR DECaMP 20:30 - 21 :00 0.50 WELLSR OTHR DECaMP 21 :00 - 00:00 3.00 WELLSR TRIP DECaMP 3/26/2003 00:00 - 07:30 7.50 WELLSRTRIP DECaMP 07:30 - 08:30 1.00 WELLSRWASH DECaMP 08:30 - 09:00 0.50 WELLSR OTHR DECaMP 09:00 - 09:30 0.50 WELLSR OTHR DECOMP 09:30 - 11 :00 1.50 WELLSR CIRC DECOMP 11 :00 - 21 :00 10.00 WELLSR TRIP DECOMP 21 :00 - 21 :30 0.50 WELLSR OTHR DECaMP 21 :30 - 22:30 1.00 WELLSR OTHR DECaMP 22:30 - 00:00 1.50 WELLSRTRIP DECaMP 3/27/2003 00:00 - 01 :30 1.50 WELLSR TRIP DECaMP 01 :30 - 04:00 2.50 WELLSR OTHR DECaMP 04:00 - 08:00 4.00 WELLSR OTHR DECOMP 08:00 - 14:00 6.00 WELLSR SEaT DECaMP 14:00 - 15:00 1.00 WELLSR OTHR DECaMP 15:00 - 15:30 0.50 WELLSR SEOP DECaMP 15:30 - 18:00 2.50 WELLSR OTHR DECaMP 18:00 - 00:00 6.00 WELLSR TRIP DECaMP Printed: Adjust bails on Top Drive to clear Monkey Board. Work re-adjusting COM. POOH w/ Plug Plucker Repair Drill collar slips POOH wI BHA Break extension apart, redress latch up tool, attempt to M/U extension. Threads galled. UD extension, Top sub & latch up tool. Send tools to Baker to be machined. Clean rig & Mix OBM while waiting on Tools. Wait on extension & Top Sub threads to be re-cut. M/U Fishing assy. / BHA & RIH w/ 5-1/2" DP to 16440' Wash down to the top of CIBP & attempt to latch up. No success. Tag top of CIBP @ 16462' rotating, 16466' slacking off. Mill up slips on CIBP. Push down to 16477' Circulate Bttms up, Monitor well (static), Pump dry job. POOH w/ Plug Plucker assy. POH w/5-1/2"dp LD junk bskts, top sub, xtensn, shoe, & plucker. clear floor. Recov'd 1/4 cup from JBskts, + 3each 1/4" thick x 1" wide bands approx 8-1/2" 00. from shoe body. Service rig, clean floor after emptying JBskts. PU overshot w/6-3/" grapple & control, PU BHA, 15 min PJSM RIH w/ ovrshot & 5-1/2" DP Calibrate weight indicator w/ anadril, change out oil in load cell TIH w/ a-shot 1930' to 4870' clean rig floor of OBM PJSM, cut 104' drlg line Service rig, draw works,crown, & brakes Cont. TIH RIH wI 5-1/2" DP and Overshot-clean rig floor Kelly up & wash to 16515 -tag fish set dn over fish set on fish @ 16515-drop dart for pump out sub pump dart dn hole w/ +/- 800psi @50 stks-dart won't go dn hole. Pump dry job- monitor well-PJSM- POOH w/ overshot to 3751'· 60 K drag first stand.-Ieveled off to +/-20K over next 5 stds attempt to shear pins in pump out sub-pinned to +/- 2000psi- press to 3000 psi wlo shearing. RU mud bucket POOH wet. POOH w/ 5-1/2" DP LD bump sub, oil jars, xo, Overshot..no fish. dart landed on xo instead of opening po sub. clean up rig floor from wet trip,clean up tools RU to test Bops. Upper ram and outside kill & HCR 250/5000psi, lower ram 250/5000 psi, Hydril250/3500. Upper kelly cock valve, floor valve, lower IBOP, upper IBOP 250/5000, blind rams 250/5000. test choke manifold valves 250/5000. test whitness waived by State. change oput gripper dies service top drive and blocks pull test plug, run wear bushing, lock dn w/2 screws clear floor, PU BHA,=shoe, extension w/ cage, drive bush, 2 junk bskts, float sub, bump sub, oil jars, disc sub Trip in hole 5/1/2003 2:15:37 PM Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: Printed: #8 WELLSR OTHR DECOMP clear floor, service rig, top drive, blocks & crown WELLSR OTHR DECOMP PU fishing assembly #8, hollow mill w. 5" 10, xo bushing, O. shot 5/1/2003 2:15:37 PM 5:30 16:30 6:30 8:30 .00 2.00 4/2/2003 06:30 5:00 9:30 20:30 00:00 00:00 00:30 01:00 01:30 00:30 01:00 01:30 19:30 0.50 0.50 0.50 18.00 WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP 4/1/2003 3/31/2003 3/30/2003 22:30 23:30 00:00 02:00 08:00 0:30 23:30 00:00 02:00 08:00 10:30 14:00 .00 0.50 2.00 6.00 2.50 3.50 WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR CIRC DECOMP WELLSR MILL DECOMP 03:30 11:00 12:00 21:30 11:00 12:00 21:30 22:30 7.50 1.00 9.50 .00 WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSRTRIP DECOMP 3/29/2003 13:30 23:30 00:00 23:30 00:00 03:30 0.00 0.50 3.50 WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP RIH wI 5-1/2" DP & fish assbly Wash from 16476 to 16481top of fish, work over fish milled dn +1- 8" up 250K, dn 150k, rot 160K, torq 14-16k, 900#@34stks, rpm 30-50. milled wI pumps on & off wI 10-30K on it. observe well, pump dry job,POOH to 322' change elevators stand back collars LD fishing assmebly #4, -shoe, extension wI basket catch, junk bskts..PU fishing assembly #5-short catch overshot RIH wI 5-1/2" fill every 4000' wash dn to top of fish, work over fish. monitor well, pump dry job, POOH wI 5-1/2" from 16481 to 308' change out elevators stand back collars, LD fishing assembly #5, recovered fish (CIBP) clear floor, clean floor, service top drive, crown and blocks Load floor wI fishing assembly #6 PU fishing ass'y #7- mill,ext, top bushing, 2-Junk bskts. clear floor RIH wI DP, fill pipe every 4000' Circ and condition mud while rot and recip from 16,386 to 16475 tag fish at 16481 , mill on fish wI 10k and 14K torque, fell through and bottomed out wI mill at 16491' monitor well, pump dry job work over fish POOH from 16491 to 324' change elevators & POOH wI 3 stds collars Lay down shoe, extension, top bushing, junk bskts,Junk bskts empty, PU overshot dressed wI 5" grapple, remove packoff,extension, top sub, clear floor RIH wI fishing assembly #8 Stop to fill pipe & slip and cut drilling line, Top drive failure, down to investigate electrical problem on upper track service loop, weld up draworks brake water jacket cut and slip 123' drilling line fill pipe repair top drive service loop RIH wI fishing assembly #8 to 16471 PU single, brk circ, work over fish tag fish @ 16484, UP 230K, dn 140k, rot 180k, rotate wI 25 rpm & 14k ft-Ibs, 30 stk/.min wI 750 psi, continue to try and work over top of fish. Monitor well, pump dry job LD single, POOH wI 1 st stand Derrickman down on board. Evacuate injured derrickman off rig Stand down for accident investigation, OSHA on site.OSHA rep Steve Standley. Prejob safety meeting. POOH from 16373 to 15417 Repair water leaak on draworks Repair water leak on Draworks D.S. brake flange- remove brake guard, chain guard, etc-grind off old epoxy and weld. repair wI welded plate 3" x 12" - install all guard & check clearances. POOH wI 5-1/2" dp.to 311' change out elevators, stnd back 3 stnds of collars. fishing assenbly 5:00 5:30 20:30 00:00 06:30 8.50 0.50 .00 3.50 6.50 WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSRTRIP DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP LD 2:30 14:00 14:30 16:30 22:00 14:00 14:30 15:00 23:30 00:00 03:30 05:00 4:00 4:30 16:30 22:00 00:00 14:30 15:00 23:30 00:00 03:30 05:00 12:30 .50 0.50 2.00 5.50 2.00 0.50 0.50 8.50 0.50 3.50 .50 7.50 WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSR TRIP WELLSRTRIP WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP DECOMP DECOMP 3/28/2003 00:00 03:00 03:00 13:30 3.00 0.50 WELLSR TRIP WELLSR MILL DECOMP DECOMP Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: ') ) dressed 5", extension, top sub. PU 3 stds drill RIH wI fishing assembly to 15137' RIH wI 5-1/2" DP Circ mill on fish @16484' 260k up, 145k dn, 190k rot, 60 stks @950#, mill wI 10-20k wob and 20 to 80 18k ft Ibs. dry drill +1- 90% of time monitor well, pump dry job. POOH POOH w/1 std. stby for spill drill wI agencies. POOH wI 5-1/2" DP to 317' change elevators. stand back 3 stds DC's and LD fishing assembly #8. Mill (8-118" ODx5" 10) internal taper has wear marks approximately 2" deep on the 10, indicating 6" 00 fish looking up. clear floor and clean. RU to test BOPs Test BOP's test choke manifold valves 250 10,5000# hi. test BOP dart valve, HCR, choke and kill line 250 10 , 5000 hi, test floor valve, outside kill & manual choke 250 10, 5000hi, test inside kill to 250 10, 5000hi, test bottom rams 25010, 5000hi, test hydril 250/3500 # Test blinds, upper & lower kelly valves, 200/5000 psi, test Koomey RD test equipment, set wear bushing PU fishing ass'y #9, 3-1/4" spear wI 4.01" grappel, bump sub, oil jars, disc sub RIH wI 5-1/2" DP filling at 4978, 9706 PU single, brk circ 290 up, 140 dn, 180 rot, w/13k ft-Ibs @ 20 rpm, 16 stks @ 450psi, slid into PBR wI spear, PU 30K over let oil jars bleed of pull up and pull PBR free wlo rotation. LD top single, pump pill, POOH 16484 - 312 change out elevators, stnd back 3 stds drill collars & BHA, recover PBR. LD spear and PBR MU packer mill and retrieving tool RI H wI 5-1/2" DP to 9714' taking torq & drag readings every 20 stands fill DP slip & cut 92' drlg line, torq deadman remove block hanging line RIH to 16479, take torq & drag every 20 stands. Kelly up on stand 171, circ and condition mud prior to milling Sting into mill out extension, and mill on production packer @ 16845' 235 up, 145 dn, 185 rot, torq 12-18K @ 45 rpm wI wt on mill @ 10k Milling on packer from 16488 to 16491' wI 20-40rpm & 10-30k wob, torq-13-15k ft-Ibs, 240k up, 145 dn, 185 rot, pkr turned loose, no PU wt. chased packer to 16493. kelly dn circ BU max gas 1300 units spr #2 pump @30stks=490psi, @45 stks=660 psi. final gas 112 units PU single #515, RIH to 16523, set dn wI 50k engage fish. monitor well fill trip tank, pump pill POOH 16523 to 1658', Pull40K over string wt from 16515 to 16440'. & from 16320 to 16300, pulled 30k over @ 1 0165. on bottom 275 up, 140 dn, max pull 310k POOH from 1666 to 320' change elevators POOH wI BHA #10 -no fish- LD PRT ass'y & bit sub, clean Jnk Bskts, recovered shavings from pkr. cup above grappel shows junk marks. cup & grappel still free. Redress spear wI 4.010 grappel 04:00 - 05:00 00:00 - 02:00 02:00 - 03:30 03:30 - 04:00 .00 2.00 1.50 0.50 WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP Printed: 5/1/2003 2:15:37 PM 4f7 12003 3:00 13:30 14:00 3:30 14:00 00:00 0.50 0.50 0.00 WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP 4/6/2003 0:30 11:00 00:00 00:00 00:30 03:00 10:00 13:00 17:00 9:00 11 :00 3:00 00:30 03:00 10:00 13:00 17:00 - 19:00 00:00 0:30 0.50 2.00 0.50 2.50 7.00 3.00 4.00 2.00 5.00 0.50 WELLSR MILL WELLSR CIRC WELLSR MILL WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR CrRC DECOMP WELLSR MILL DECOMP DECOMP DECOMP DECOMP 4/5/2003 15:30 23:00 23:00 00:00 7.50 1.00 WELLSR TRIP WELLSR TRIP DECOMP DECOMP 4/4/2003 06:00 14:30 00:00 03:00 04:00 20:00 21:30 09:30 10:00 11 :00 19:00 14:30 5:30 03:00 04:00 06:00 21:30 00:00 - 10:00 11:00 19:00 20:00 8.50 1.00 3.00 1.00 2.00 1.50 2.50 0.50 1.00 8.00 1.00 WELLSR TRIP WELLSR TRIP WELLSR SEQT DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR SEOT DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP DECOMP DECOMP 4/3/2003 6:30 8:30 00:00 01:30 02:00 18:30 00:00 01:30 02:00 09:30 2.00 5.50 1.50 0.50 7.50 WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR CIRC DECOMP WELLSR MILL DECOMP reference pump press rpm, torq 14.5fVlbs to 4/2/2003 collars, change elevators. Legal Well Name: Common Well Name Event Name: Contractor Name Rig Name: HANSEN #1 HANSEN #1 ROT - SIDETRACK Nabors Alaska Drilling Nabors 273 Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: ) ') PU BHA #11, spearw 4.010 grappel, xO,xo,xo,bump sub, sub,xo 9-6" DC=306.87'. RIH, change elevators RIH to 16466' kelly up @ 16466 brk circ, work over fish wI pumps on. press increase PU wI 3-5k wt increase. set dn uo 275k, dn 140k circ BU max gas=1150 units SPR#2 pump 30 stks @500 psi, 45 stks @ 700 psi, #3 pump 30stks @ 500 psi, 45stks @ 675 psi. observe well pump dry job, LD 2 singles, no weight no drag. PU 2 singles, work over fish, gain 3-5k POOH from 16523 to 8616, pull 1 Ok over string wt at 10120, Continue POH-No fish recovered. Remove fishing spear & grapple-redress spear wI new grapple. Service rig,blocks,crown check brakes-work on hydraulic leaks-top drive & clean rig floor. Make up spear wI new grapple & stop-grapple size 4.010" RIH wI fishing assembly. Attempting to latch onto fish-appears to have not engauged-pump pressure increase when spear enters fish-Pressure drops off when picking up . CBU-250 units gas on bottoms up. POH wI fishing tools. POH to Jars. Work fish free-Packer hung up in wear ring. Clean floor-lay down fishing assembly. Rig up to lay down tbg. & lay down 12 jts. 3.5" tbg. & 2 slotted jts. PJSM-Lay down 22 perf guns-all shots fired-rig down handling tools & clean floor. Pull wear ring & service sameOset wear ring. RIH w/6 1/4" dc,s & poh laying down dc,s-lift subs & xo subs. PJSM-Pick up tools & equipment for clean out run to rig floor. Make up 7" scraper & boot basket-pick up 9 4 3/4" dC,s-make up 9 5/8" scraper wI 2 boot baskets. RI H to 16592' checking torque & drag from 3500' every 10 stands CBU @ 5005' & 10204'. PJSM-Cut & slip drlg. line. CBU while cutting line. Finish CBU. PUW 255k SOW 150k RW 200k TQ 15k. (BHA #13 61/8" bit·7" scraper-2 boot baskets-bit sub-bumper sub-oil jars-9 4 3/4" dC,s-4 xO,s-9 5/8" scraper-2 boot baskets-bit sub-xo-5 1/2" dp. Finish cbu. RIH-tagged @ top of liner wI locator sub-bit @ 16942'. Circulate hole clean-monitor well-pump pill. POH wI clean out assembly-lay down bha-stand back 4 3/4" dC,s-clean junk baskets-recovered 3 larger chunks of iron & cup full of fines. Clean obm off bha & remove from floor-pull wear ring. Test bope 250-5000#. (Witness test waived by John Crisp AOGCC) Finish testing bope-rig down test tools & equipment-set wear ring & clean rig floor. Make up bridge plug assembly-drifted 4 3/4" dc,s w/1 1/2" ball & rih. RIH wi bridge plug @ 2 mins. per stand as per baker rep. Work bridge plug into liner top-run into liner tie back sleeve 6'-attempt to work bridge plug down-plug stuck in tie back sleeve-work free-monitor well. (stuck @ 16632') Finish cbu & mix pill. 22:30 01:30 03:00 8:30 00:00 03:00 18:30 22:30 .50 .50 5.50 4.00 WELLSR CIRC WELLSR PULD DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP DECOMP Printed: 5/1/2003 2:15:37 PM 4/12/2003 9:00 20:00 00:00 20:00 00:00 01:30 .00 4.00 .50 WELLSR OTHR DECOMP WELLSR SEaT DECOMP WELLSR SEaT DECOMP 00:00 00:30 03:30 06:00 00:30 03:30 06:00 9:00 0.50 3.00 2.50 13.00 WELLSR CIRC WELLSR TRIP WELLSR CIRC WELLSR TRIP DECOMP DECOMP DECOMP DECOMP 4/11/2003 22:30 - 23:30 23:30 - 00:00 23:00 00:00 01:30 03:30 11 :00 - 22:30 00:00 01:30 03:30 11 :00 .00 0.50 11.50 .00 .50 2.00 7.50 WELLSR OTHR DECOMP WELLSR CIRC DECOMP WELLSR TRIP WELLSR OTHR DECOMP WELLSR PULD DECOMP WELLSR PULD DECOMP WELLSR PULD DECOMP DECOMP 4/1 0/2003 4/9/2003 20:00 23:00 00:00 0:00 3:00 5:00 8:30 10:30 11:30 8:00 23:00 00:00 10:00 13:00 15:00 18:30 23:00 11:30 18:00 20:00 3.00 1.00 0.00 3.00 2.00 3.50 4.50 .00 6.50 2.00 WELLSR CIRC WELLSR TRIP WELLSR TRIP WELLSR OTHR WELLSR PULD WELLSR PULD WELLSR PULD WELLSR PULD DECOMP WELLSR TRIP DECOMP WELLSR OTHR DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 4/8/2003 6:30 - 17:00 17:00 - 18:00 18:00 - 00:00 00:00 - 07:00 07:00 - 08:30 08:30 - 10:30 5:00 16:30 0.50 1.00 6.00 7.00 1.50 2.00 .50 WELLSR OTHR DECOMP WELLSR OTHR DECOMP WELLSR TRIP DECOMP WELLSR TRIP DECOMP WELLSR PULD DECOMP WELLSR OTHR DECOMP WELLSR CIRC DECOMP 06:30 14:00 14:00 15:00 7.50 .00 WELLSR TRIP DECOMP WELLSR OTHR DECOMP 41712003 05:00 - 06:30 .50 WELLSR OTHR DECOMP jar, disc Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: ~) ') Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Event Name: ROT - SIDETRACK Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 273 4/13/2003 00:00 - 01 :00 1.00 WELLSR CIRC DECaMP 01 :00 - 10:00 9.00 WELLSR TRIP DECOMP 10:00 - 11 :00 1.00 WELLSR PULD DECaMP 11 :00 - 15:30 4.50 WELLSR PULD DECaMP 15:30 - 17:30 2.00 WELLSR TRIP DECaMP 17:30 - 18:30 1.00 WELLSR CIRC DECaMP 18:30 - 20:30 2.00 WELLSR TRIP DECaMP 20:30 - 21 :30 1.00 WELLSR CIRC DECaMP 21 :30 - 22:00 0.50 WELLSR TRIP DECaMP 22:00 - 22:30 0.50 WELLSR OTHR DECaMP 22:30 - 00:00 1.50 WELLSR TRIP DECaMP 4/14/2003 00:00 - 03:00 3.00 WELLSR OTHR DECaMP 03:00 - 04:00 1.00 WELLSR CIRC DECaMP 04:00 - 13:00 9.00 WELLSR TRIP DECaMP 13:00 - 14:00 1.00 WELLSR PULD DECaMP 14:00 - 17:00 3.00 WELLSR TRIP DECaMP 17:00 - 17:30 0.50 WELLSR OTHR DECaMP 17:30 - 22:30 5.00 WELLSR TRIP DECaMP 22:30 - 00:00 1.50 WELLSR OTHR DECaMP 4/15/2003 00:00 - 01 :00 1.00 WELLSR TRIP DECaMP 01 :00 - 01 :30 0.50 WELLSR TRIP DECaMP 01 :30 - 03:00 1.50 WELLSR CIRC DECaMP 03:00 - 10:00 7.00 WELLSR TRIP DECaMP 10:00 - 10:30 0.50 WELLSR TRIP DECaMP 10:30 - 11 :00 0.50 WELLSR OTHR DECaMP 11 :00 - 13:30 2.50 WELLSR TRIP DECaMP 13:30 - 15:30 2.00 WELLSR OTHR DECaMP 15:30 - 17:00 1.50 WELLSR TRIP DECaMP 17:00 - 22:00 5.00 WELLSR TRIP DECaMP 22:00 - 22:30 0.50 WELLSR OTHR DECaMP 22:30 - 00:00 1.50 WELLSRTRIP DECaMP 4/16/2003 00:00 - 01 :00 1.00 WINDOWSETW DECaMP 01 :00 - 01 :30 0.50 WINDOWOTHR DECaMP 01 :30 - 05:00 3.50 WINDOWTRIP DECaMP 05:00 - 05:30 0.50 WINDOWTRIP DECaMP 05:30 - 06:00 0.50 WINDOWOTHR DECaMP 06:00 - 06:30 0.50 WINDOWTRIP DECaMP 06:30 - 07:30 1.00 WINDOWCIRC DECaMP 07:30 - 08:30 1.00 WINDOWOTHR DECaMP 08:30 - 09:00 0.50 WINDOWOTHR DECaMP 09:00 - 16:30 7.50 WINDOWTRIP DECaMP 16:30 - 18:00 1.50 WINDOWOTHR DECaMP 18:00 - 19:30 1.50 WINDOWTRIP DECaMP 19:30 - 20:00 0.50 WINDOWOTHR DECaMP 20:00 - 22:00 2.00 WINDOWSETW PROD Printed: PJSM-Finish cbu-monitor well & pump pill. POH wI 5.5" dp. POH wI bha & baker running tool-bridge plug left in hole-bolt broke on bottom of running tool. Clean rig floor-pick up & make up milling assembly-pick up 34 3/4" dc,s RIH wI milling assembly to 6014'. Fill pipe & cbu. RI H wI milling assembly to 11703'. Fill pipe & cbu. RIH wI milling assembly to 12565'. Service rig-change dies on grabber. RIH wI milling assembly to 16572'. Tagged Bridge plug @ 16632'-work same loose & chase down hole to 16954'. Circ. hole clean-monitor well-pump pill. POH for jet basket-lay down milling assembly. Clean junk baskets-clear floor-make up jet basket. RI H wI jet basket. Service rig & top drive. Finish rih to 16587'. Wash wI jet basket from 16587 to 16936'. Cont to wash wI jet bskt 16936' to 16937. 9-5/8" scraper tagged TaL @ 16,617 Pump out of hole 16,937 to 16,587'. Tagged TaL wI jet bsket @ 16,617' while working pipe Cic BU, monitor well, pump dry job POOH, change elevators POOH wI 4" dp, change elevators LD xo's, bit sub, 9-5/8" csg scrapers POOH wI 4-3/4" DC's, LD jet bsket ssy. clean junk bskets, Rcov'ed large pieces of slips & smaller metal pieces from JB's and jet bskt, approx 16 fluid oz ( 1 cup). 1" gouge approx 1/4" deep on jar mandril. Change out to long bails, pjsm, adjust same, check at board and crown -o-matic PU & MU running tool and CIBP, RIH wI 4" DP, PU 3 jts of 4" DP RIH wI CIBP on 5-1/2" DP @ 2min I std to 7312 spot 5 bbl pill weighted to 10.2 #, adjust bail clamps RIH to 10167 RIH wI CIBP from 10167 to 10738. Pipe running over tripping in. Pump 5 bbl , 10.6# weighted pill RIH 10783 to 16,900' Pull CIBP to 16,880' and set on depth Drop ball, Pump dn ball and set plug at 16880 POOH to 16828' Circ BU Test CIBP to 1700 psi for 30 min. on chart. Hebert. monitor well pump dry job. POOH 16,828 to 2167 cut 110' drlg line, adjust brakes POOH with CIBP running tool. clean floor and LD running tool PU & MU starter mill, 2 string mills, t 3-1/2" Whitness waived by Winton hwdp, 5/1/2003 2:15:37 PM MWD Start: Rig Release: Rig Number: 273 3/6/2003 Spud Date: 8/30/2001 End: Group: ) onsSummaryReport Legal Well Name: HANSEN #1 Common Well Name: HANSEN #1 Spud Date: 8/30/2001 Event Name: ROT - SIDETRACK Start: 3/6/2003 End: Contractor Name: Nabors Alaska Drilling Rig Release: Group: Rig Name: Nabors 273 Rig Number: 273 Date From ~ To Sub Phase Description of Operations Hour$ '.' O.odE}.Code 4/16/2003 22:00 - 22:30 0.50 WINDOWSETW PROD Test MWD 22:30 - 23:30 1.00 WINDOWSETW PROD PU whipstock and MU to starter mill 23:30 - 00:00 0.50 WINDOWSETW PROD RIH with whipstock & 4-3/4" DC's 4/17/2003 00:00 - 00:30 0.50 WINDOWfRIP PROD Finish RIH wI 4-3/4" DC's, change elevators to 4" 00:30 - 01 :00 0.50 WINDOWOTHR PROD Reposition 4" DP in derrick, change elevators to 5-1/2" ,/ 4 SHEET HOR Z. SCAU:'" . ,:OCf \'tR'. SCAU: HfA OAWC. /to.01J<)97 CH£O<ED BT ORA.... BY PCO ï t ~: \j- ~! F l' h.. .- tI ~~- ~ I-" !~~ ð h: Q!~! \,I ~i ~ F ~ .)- i ~ C.)~ ~: .E~ a % ..0 ~ ~ m~ 0- ~~ ~à: ml! -~ g <~ 0 s CJ)~ ~ ~ e:~ Q I ..L. ~ <> .J~ a g -:8 <- J:~ Q.._ Q. 0( "-: € {jJ=eJ ~ ~ - ... z ~ ~ ~ ~; 1;; " I ~ ¡¡;¡ ~ !/! ,. ¡;¡ ~ % .. 0 ~ ~ ~ ~ I I: to. ~~t!.~ \ ~. 1 '/,r"· ~.;.!_: ",\\\~"....~"" FOUND GlO BRASS CAPPEO r 1oI0000IoIENT, 1918 SEC. 2 ¡ SEC. 1 SEC. 11 SEC. 12 ~ J (0 ~DI' RECORD 'OUND ,. NOTES I) HORIZONTAl OAW" BASED OH us STATE Pl»IE COOIDIHA1tS Ig27, AlASKA ZONE 4. "OHI.&IÐ<T US{D 'OR BASIS or COOf!OIIAI[S WAS NCS WOHU\l£HT H 86. COORDINATES Fa! tHIS WCHU\o4ENT >ERE EST_EO BY !>IE STATE or ALASKA DfPAlmlElCT (;# m....sPORTAl1ON foKJ PUBlIC FAOU1I£S GEOIIEFERÐ<OHG PRo.£CT PHASE I ....0 .. 2) ~GS SHO.... _ON ARE ORJD. BASIS OfF eu..o.<GS IS fROOI A STA l1C CPS BASEIJI€ OIISEIIVA l1ON. J) 'ÆR11C.U. OA1IIW IS BASED OH HAW Dð OAWW. WOH'-"lHT usrn fOfI BASIS or FJ.£VA1IQ<S WAS HGS , ( HJ , [HT H 86 (El£V'.'eG.II4') ') SECTION LINES _ IO£OH ARE BASED ON DATA or RECORD, 5) SUN£'( COHOIIC1m BY "cLUE: ~11HG GROUP -- AUGUST 27, 2001 I>IROUGH SEP1EJ«R os. 2001. ~ 1::", ~~ ~ô ¡:: ~ 1"''''-'''- , -, f ~::JJ:G NtÄD' I , , ! J ,--...... I HAHSEN NO. I \OWJ£AI) I ./ V ' GRID H: 2'<4659.501 ...'" 'r I ~~'~098' , l0NGl1UOE: 15"008"05.720" I \ I EL£Y.s"5.1' (GRaJlC) . 'IIÐ1J , ,r\ , I I \ II 1S27 .fEL í ' \ ' I I ,-'- L........... ¡ .. ~ I ---.I ~~~ .s:s'-i'~..J1 " \ 'I \ , It \\ \\ \ '----:====-,:'. ---- \\ \\ \\ \' }; 11 11 1/ 11 11 II II II II 1/ I f \\ \\ \ \ " II 11 (( Hðð"2TOO'W SECTION U/t£ SECTION 2. TOYItISHIP 4 SOtmI, RANGE t 5 ~'. S.N.. AlASKA 2148' F9. I I , j / , ~ : tf I::J if å, ~ I 12/ I I I I I I / / I / / / JAN 0 8 2003 Alaska Oil & G~~ Cons. Commission Anchorage ,- RECEIVED ~, i ooJ L_,~J L~,--.i L__~-J L~J Lj L---i L-i L-i L-j LJ '--i L....J LJ L.J L-J l...--i L-.i I~ = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 1 ot 9 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 Survey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT ,I\TTEQ. WELL DATA Target TVD (F1) Target Coord. N/S Slot Coord. NIS 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section ·N(+)/S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DO) (F1) (F1) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) ~. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 2;¿-OCT-01 MWD 495.00 0.00 0.00 495.00 495.00 0.00 0.00 0.00 0.00 0.00 ASSUMED VERTRICAL 30-0CT-01 MWD 741.00 1.60 32.30 246.00 740.97 -0.28 2.90 1.84 0.65 0.65 30-0CT-01 MWD 835.00 1.80 348.40 94.00 834.93 0.54 5.46 2.24 1.37 0.21 30-0CT-01 MWD 927.00 2.00 260.40 92.00 926.90 2.73 6.61 0.37 2.87 0.22 30-0CT-01 MWD 1025.00 4.80 256.80 98.00 1024.71 7.20 5.38 -5.31 2.86 2.86 30-0CT-01 MWD 1118.00 7.50 272.70 93.00 1117.18 15.66 4.78 -15.17 3.41 2.90 17.10 30-0CT-01 MWD 1211 .00 10.00 286.30 93.00 1209.10 29.09 7.33 -28.98 3.47 2.69 14.62 30-0 CT-O 1 MWD 1307.00 12.80 292.30 96.00 1303.20 47.86 13.71 -46.83 3.16 2.92 6.25 30-0CT-01 MWD 1401 .00 15.50 293.90 94.00 1394.34 70.77 22.75 -67.95 2.90 2.87 1.70 30-0CT-01 MWD 1495.00 17.80 296.00 94.00 1484.39 97.67 34.14 -92.35 2.53 2.45 2.23 30-0CT-01 MWD 1589.00 20.40 298.00 94.00 1573.21 128.42 48.13 -119.73 2.85 2.77 2.13 ~-OCT-01 MWD 1684.00 22.70 298.00 95.00 1661 .56 163.31 64.51 -150.54 2.42 2.42 0.00 oJ I-OCT-01 MWD 1775.00 25.00 300.30 91.00 1744.79 200.08 82.46 -182.65 2.73 2.53 2.53 31-0CT-01 MWD 1866.00 27.70 300.80 91.00 1826.32 240.41 103.00 -217.43 2.98 2.97 0.55 31-0CT-01 MWD 1959.00 30.10 301 .20 93.00 1907.74 285.27 126.15 -255.95 2.59 2.58 0.43 31-0CT-01 MWD 2052.00 32.80 300.70 93.00 1987.07 333.70 151.09 -297.56 2.92 2.90 -0.54 31-0CT-01 MWD 2144.00 35.20 300.70 92.00 2063.33 385.07 177.36 -341.79 2.61 2.61 0.00 31-0CT-01 MWD 2239.00 38.40 299.90 95.00 2139.39 441 .90 206.05 -390.93 3.41 3;37 -0.84 31-0CT-01 MWD 2333.00 41.20 300.60 94.00 2211 .61 502.00 236.37 -442.89 3.02 2.98 0.74 31-0CT-01 MWD 2426.00 43.20 300.90 93.00 2280.50 564.37 268.31 -496.58 2.16 2.15 0.32 31-0CT -01 MWD 2519.00 45.50 300.80 93.00 2347.00 629.27 301 .65 -552.38 2.47 2.47 -0.11 01-NOV-01 MWD 2610.00 48.30 299.00 91.00 2409.17 695.64 334.74 -609.99 3.40 3.08 -1.98 01-NOV-01 MWD 2704.00 51.60 297.00 94.00 2469.65 767.58 368.49 -673.52 3.87 3.51 -2.13 ~ ~ ~ ~ L--.i L-.M L-i L-..â L..i L-.I L-i L.J L--i L..i L..J L-.J L..i L-I L-J = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 2 of 9 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 Survey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT 'NTEQ WELL DATA Target TVD (81 Target Coord. NIS Slot Coord. NIS 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSD Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Vertical Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fl) (DO) (DO) (Fl) (F1) (Fl) (Fl) (Per 100 Fl) Drop (-) LeftH ,...-... J OV -01 MWD 2798.00 53.40 297.60 94.00 2526.87 842.15 402.69 -739.78 1.98 1.91 0.64 01-NOV-Q1 MWD 2894.00 55.20 297.60 96.00 2582.89 920.11 438.81 -808.87 1.88 1.88 0.00 01-NOV-01 MWD 2988.00 57.70 296.40 94.00 2634.84 998.44 474.36 -878.67 2.86 2.66 -1.28 01-NOV-01 MWD 3084.00 59.50 296.60 96.00 2684.85 1080.36 510.92 -952.00 1.88 1.88 0.21 01-NOV-01 MWD 3178.00 61.50 297.1 0 94.00 2731 .14 1162.1 6 547.88 -1024.98 2.18 2.13 0.53 01-NOV-01 MWD 3270.00 64.20 296.40 92.00 2773.12 1244.01 584.71 -1098.08 3.01 2.93 -0.76 01-NOV-01 MWD 3362.00 67.40 297.30 92.00 2810.82 1327.91 622.62 -1172.93 3.59 3.48 0.98 02-NOV-01 MWD 3456.00 70.20 298.00 94.00 2844.81 1415.54 663.29 -1250.55 3.06 2.98 0.74 02-NOV-01 MWD 3551 .00 72.90 297.90 95.00 2874.88 1505.64 705.52 -1 330.15 2.84 2.84 -0.11 04-NOV-01 MWD 3660.00 73.40 298.30 109.00 2906.47 1609.96 754.66 -1422.18 0.58 0.46 0.37 04-NOV-01 MWD 3754.00 73.40 297.90 94.00 2933.33 1700.03 797.08 -1501.64 0.41 0.00 -0.43 04-NOV-01 MWD 3848.00 73.40 297.70 94.00 2960.18 1790.12 839.10 -1581.32 0.20 0.00 -0.21 ~-NOV-01 MWD 3944.00 73.40 297.30 96.00 2987.61 1882.11 881 .58 -1662.93 0.40 0.00 -0.42 04-NOV-01 MWD 4036.00 73.20 297.40 92.00 3014.04 1970.23 922.06 -1741.20 0.24 -0.22 0.11 04-NOV-01 MWD 4130.00 73.20 297.70 94.00 3041.21 2060.22 963.68 -1820.98 0.31 0.00 0.32 04-NOV-01 MWD 4225.00 73.40 297.60 95.00 3068.51 2151 .21 1005.91 -1901.58 0.23 0.21 -0.11 04-NOV-01 MWD 4319.00 73.50 297.40 94.00 3095.29 2241 .32 1047.52 -1981.51 0.23 0.11 -0.21 04-NOV-01 MWD 4412.00 73.30 297.90 93.00 3121.86 2330.44 1088.88 -2060.45 0.56 -0.22 0.54 04-NOV-01 MWD 4508.00 73.50 297.90 96.00 3149.28 2422.44 1131.92 -2141 .76 0.21 0.21 0.00 04-NOV-01 MWD 4603.00 73.40 298.10 95.00 3176.35 2513.50 1174.68 -2222.16 0.23 -0.11 0.21 04-NOV-01 MWD 4697.00 73.40 298.00 94.00 3203.20 2603.58 1217.04 -2301 .66 0.10 0.00 -0.11 04-NOV-01 MWD 4791.00 73.40 297.90 94.00 3230.05 2693.66 1259.26 -2381.24 0.10 0.00 -0.11 04-NOV-01 MWD 4885.00 73.50 296.90 94.00 3256.83 2783.77 1300.72 -2461.24 1.03 0.11 -1.06 04-NOV-01 MWD 4980.00 73.50 296.40 95.00 3283.81 2874.84 1341.58 -2542.65 0.50 0.00 -0.53 L-i L-J 1-J L-.J L-J l...-.J 1--J .1-.J L.....J L-J L-J L..J L-J i . . Î . A j . L-L ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 3 of 9 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 Survey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT INTEQ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ;--'\JOV-O1 MWD 5073.00 73.30 296.50 93.00 3310.38 2963.95 1381.28 -2622.44 0.24 -0.22 0.11 05-NOV-01 MWD 5151 .00 74.00 297.20 78.00 3332.34 3038.79 1415.08 -2689.22 1.24 0.90 0.90 26-NOV-01 MWD 5275.00 73.20 298.90 124.00 3367.35 3157.73 1471 .01 -2794.20 1.46 -0.65 1.37 26-NOV-01 MWD 5370.00 73.20 298.70 95.00 3394.81 3248.66 1514.83 -2873.89 0.20 0.00 -0.21 26-NOV-O1 MWD 5464.00 73.30 298.50 94.00 3421 .90 3338.65 1557.92 -2952.92 0.23 0.11 -0.21 26-NOV-01 MWD 5558.00 73.20 298.30 94.00 3448.99 3428.65 1600.73 -3032.1 0 0.23 -0.11 -0.21 26-NOV-01 MWD 5652.00 73.20 298.10 94.00 3476.16 3518.64 1643.25 -3111.40 0.20 0.00 -0.21 26-NOV-Q1 MWD 5745.00 73.20 297.80 93.00 3503.04 3607.66 1684.98 -3190.05 0.31 0.00 -0.32 26-NOV-01 MWD 5839.00 73.30 297.90 94.00 3530.13 3697.67 1727.03 -3269.64 0.15 0.11 0.11 26-NOV-01 MWD 5932.00 73.40 297.60 93.00 3556.78 3786.77 1768.52 -3348.49 0.33 0.11 -0.32 26-NOV-01 MWD 6025.00 73.60 297.40 93.00 3583.19 3875.94 1809.69 -3427.58 0.30 0.22 -0.22 27-NOV-01 MWD 6117.00 73.30 296.90 92.00 3609.40 3964.13 1849.93 -3506.06 0.61 -0.33 -0.54 ~7-NOV-01 MWD 6210.00 73.20 297.10 93.00 3636.20 4053.18 1890.36 -3585.40 0.23 -0.11 0.22 27-NOV-01 MWD 6305.00 73.30 296.80 95.00 3663.58 4144.14 1931.59 -3666.49 0.32 0.11 -0.32 27 -NOV-01 MWD 6398.00 73.10 296.40 93.00 3690.46 4233.16 1971 .45 -3746.10 0.46 -0.22 -0.43 27-NOV-O1 MWD 6493.00 73.20 296.00 95.00 3718.00 4324.06 2011 .60 -3827.68 0.42 0.11 -0.42 27 -NOV-01 MWD 6586.00 73.10 296.00 93.00 3744.95 4413.03 2050.61 -3907.68 0.11 -0.11 0.00 27-NOV-01 MWD 6678.00 73.30 296.30 92.00 3771 .54 4501 .08 2089.43 -3986.74 0.38 0.22 0.33 27-NOV-01 MWD 6774.00 73.60 296.10 96.00 3798.89 4593.08 2130.06 -4069.31 0.37 0.31 -0.21 27 -NOV-01 MWD 6868.00 73.10 296.00 94.00 3825.82 4683.10 2169.61 -4150.22 0.54 -0.53 -0.11 27-NOV-01 MWD 6962.00 73.30 295.60 94.00 3852.99 4773.05 2208.77 -4231.23 0.46 0.21 -0.43 27-NOV-01 MWD 7057.00 73.10 295.80 95.00 3880.45 4863.95 2248.21 -4313.18 0.29 -0.21 0.21 27 -NOV-01 MWD 7150.00 73.20 295.80 93.00 3907.41 4952.91 2286.95 -4393.32 0.11 0.11 0.00 27 -NOV-01 MWD 7245.00 73.20 296.20 95.00 3934.87 5043.83 2326.82 -4475.06 0.40 0.00 0.42 b-=-' L..J I=.......J --=' -==' .---1 '---I ...--J .--..1 '-=--1 ~---1 '.~ '--i --i '--i '--i .----M '.--J '-l = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 4 of 9 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 Survey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT 11v.~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSD Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURYATURE Target Direction (OD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Yertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+)/W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ~ JOY-01 MWD 7339.00 73.10 296.20 94.00 3962.11 5133.77 2366.54 -4555.78 0.11 -0.11 0.00 28-NOY-01 MWD 7432.00 73.20 296.30 93.00 3989.07 5222.75 2405.91 -4635.61 0.15 0.11 0.11 28-NOY-01 MWD 7526.00 73.40 296.40 94.00 4016.08 5312.76 2445.87 -4716.29 0.24 0.21 0.11 28-NOV-01 MWD 7619.00 73.10 296.40 93.00 4042.89 5401 .80 2485.46 -4796.05 0.32 -0.32 0.00 28-NOY-01 MWD 7712.00 73.10 296.70 93.00 4069.92 5490.77 2525.24 -4875.65 0.31 0.00 0.32 28-NOY-01 MWD 7806.00 73.30 297.10 94.00 4097.09 5580.75 2565.95 -4955.90 0.46 0.21 0.43 28-NOY-01 MWD 7900.00 73.20 297.40 94.00 4124.18 5670.76 2607.17 -5035.93 0.32 -0.11 0.32 28-NOY-01 MWD 7993.00 73.20 297.70 93.00 4151.06 5759.79 2648.34 -5114.86 0.31 0.00 0.32 28-NOY-01 MWD 8088.00 73.40 297.90 95.00 4178.36 5850.79 2690.78 -5195.35 0.29 0.21 0.21 28-NOY-01 MWD 8180.00 73.00 298.00 92.00 4204.95 5938.86 2732.06 -5273.15 0.45 -0.43 0.11 29-NOV-01 MWD 8276.00 73.10 298.10 96.00 4232.94 6030.68. 2775.24 -5354.20 0.14 0.10 0.10 29-NOY~01 MWD 8370.00 73.10 298.00 94.00 4260.27 6120.62 2817.54 -5433.57 0.10 0.00 -0.11 ?'"""' ·NOY-01 MWD 8464.00 73.10 297.90 94.00 4287.59 6210.56 2859.69 -5513.02 0.10 0.00 -0.11 29-NOY-01 MWD 8557.00 73.10 297.80 93.00 4314.63 6299.54 2901.26 -5591.70 0.10 0.00 -0.11 29-NOY-01 MWD 8650.00 73.30 298.10 93.00 4341.51 6388.57 2942.99 -5670.34 0.38 0.22 0.32 29-NOY-01 MWD 8743.00 73.00 298.30 93.00 4368.46 6477.57 2985.05 -5748.79 0.38 -0.32 0.22 29-NOY-01 MWD 8835.00 73.30 298.30 92.00 4395.13 6565.61 3026.80 -5826.31 0.33 0.33 0.00 29-NOY-01 MWD 8929.00 73.50 298.50 94.00 4421 .99 6655.69 3069.64 -5905.55 0.29 0.21 0.21 29-NOY-01 MWD 9021 .00 73.60 298.30 92.00 4448.04 6743.91 3111.61 -5983.17 0.24 0.11 -0.22 29-NOY-01 MWD 9115.00 73.10 298.00 94.00 4474.97 6833.96 3154.09 -6062.57 0.61 -0.53 -0.32 30-NOY-01 MWD 9208.00 73.10 297.20 93.00 4502.01 6922.95 3195.32 -6141.43 0.82 0.00 -0.86 30-NOY-01 MWD 9302.00 73.10 296.80 94.00 4529.33 7012.88 3236.15 -6221 .57 0.41 0.00 -0.43 30-NOY-01 MWD 9395.00 73.20 296.70 93.00 4556.29 7101 .88 3276.21 -6301.05 0.15 0.11 -0.11 30-NOY-01 MWD 9487.00 73.40 297.00 92.00 4582.73 7189.99 3316.01 -6379.67 0.38 0.22 0.33 ·~~~~~_ _J .~------' ~ ~ = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 5 of 9 -,------ Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 SUNey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT IIV .I::Q. WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA SUNey SUNey Inc\. Hole Course Total Coordinate Build Rate Walk Rate Vertical Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ~OV-01 MWD 9581 .00 73.20 297.30 94.00 4609.74 7280.03 3357.1 0 -6459.78 0.37 -0.21 0.32 ;';'v-I'\jOV-O1 MWD 9675.00 72.80 297.70 94.00 4637.22 7369.92 3398.61 -6539.52 0.59 -0.43 0.43 01-DEC-01 MWD 9770.00 73.20 298.00 95.00 4665.00 7460.77 3441.05 -6619.84 0.52 0.42 0.32 01-DEC-01 MWD 9864.00 72.70 297.40 94.00 4692.56 7550.63 3482.82 -6699.41 0.81 -0.53 -0.64 01-DEC-01 MWD 9959.00 73.40 297.70 95.00 4720.26 7641 .51 3524.85 -6779.98 0.80 0.74 0.32 01-DEC-01 MWD 10053.00 73.10 297.60 94.00 4747.35 7731 .52 3566.62 -6859.71 0.34 -0.32 -0.11 01-DEC-01 MWD 10146.00 73.00 298.30 93.00 4774.46 7820.47 3608.32 -6938.30 0.73 -0.11 0.75 01-DEC-Q1 MWD 10238.00 73.50 298.30 92.00 4800.97 7908.56 3650.08 -7015.86 0.54 0.54 0.00 01-DEC-01 MWD 10332.0Ò 73.50 297.70 94.00 4827.67 7998.69 3692.40 -7095.44 0.61 0.00 -0.64 01-DEC-01 MWD 10427.00 73.40 299.00 95.00 4854.73 8089.74 3735.64 -7175.58 1.32 -0.11 1.37 01-DEC-01 MWD 10520.00 73.20 299.80 93.00 4881 .46 8178.77 3779.37 -7253.19 0.85 -0.22 0.86 01-DEC-01 MWD 10615.00 73.30 299.70 95.00 4908.84 8269.67 3824.51 -7332.17 0.15 0.11 -0.11 ~-DEC-01 MWD 10709.00 73.20 299.60 94.00 4935.93 8359.63 3869.04 -7410.39 0.15 -0.11 -0.11 ¿-DEC-01 MWD 10804.00 73.40 298.40 95.00 4963.23 8450.59 3913.15 -7489.98 1.23 0.21 -1.26 02-DEC-01 MWD 10898.00 73.30 297.00 94.00 4990.16 8540.64 3955.01 -7569.71 1.43 -0.11 -1 .49 02-DEC-01 MWD 10992.00 73.30 . 296.20 94.00 5017.17 8630.67 3995.32 -7650.22 0.82 0.00 -0.85 02-DEC-01 MWD 11086.00 73.40 295.80 94.00 5044.11 8720.69 4034.80 -7731.16 0.42 0.11 -0.43 02-DEC-01 MWD 11181.00 72.90 . 295.60 95.00 5071 .64 8811.57 4074.23 -7813.09 0.56 -0.53 -0.21 02-DEC-01 MWD 11274.00 73.50 294.30 93.00 5098.53 8900.50 4111 .79 -7893.81 1.49 0.65 -1 .40 03-DEC-01 MWD 11364.00 74.00 294.40 90.00 5123.71 8986.77 4147.41 -7972.52 0.57 0.56 0.11 05-DEC-01 MWD 11465.00 73.40 294.00 101 .00 5152.06 9083.55 4187.15 -8060.94 0.71 -0.59 -0.40 0S-DEC-01 MWD 11559.00 73.70 294.70 94.00 5178.68 9173.56 4224.32 -8143.08 0.78 0.32 0.74 05-DEC-01 MWD 11653.00 73.50 295.70 94.00 5205.22 9263.65 4262.71 -8224.67 1.04 -0.21 1.06 05-DEC-01 MWD 11747.00 73.50 296.30 94.00 5231.91 9353.75 4302.22 -8305.68 0.61 0.00 0.64 Þ--J ' .--f .L--...J .L.........J .L.--..J .i.........J l......-; L...;; I ~ L_ _0 I .. L-J ~ L.......J L-J L-J L-J L-I L-J ~ .:.-::t = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00106 Sidetrack No. Page 6 of 9 Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - rig: #273 Field KENAI PENINSULA Well Name & No. HANSEN #1 SUNey Section Name HANSEN #1 MWD BHI Rep. T WRIGHT 'Iw.~ WELL DATA Target ìVD (F1) Target Coord. N/S Slot Coord. N/S 2209.43 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -1545.72 Magn. Declination 20.310 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 297.55 Magn. to Map Corr. 20.310 Map North to: OTHER SURVEY DATA SUNey SUNey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ìVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (F1) (DO) (DO) (F1) (F1) (FT) (FT) (Per 100 FT) Drop (-) Left (-) r'--~ )EC-01 MWD 11841.00 73.40 296.20 94.00 5258.69 9443.83 4342.08 -8386.49 0.15 -0.11 -0.11 06-DEC-01 MWD 11934.00 73.60 297.60 93.00 5285.10 9533.00 4382.42 -8466.01 1.46 0.22 1.51 06-DEC-01 MWD 12029.00 73.50 298.00 95.00 5312.01 9624.11 4424.91 -8546.60 0.42 -0.11 0.42 06-DEC-01 MWD 12122.00 73.00 297.90 93.00 5338.81 9713.16 4466.65 -8625.27 0.55 -0.54 -0.11 07 -DEC-01 MWD 12217.00 73.40 298.70 95.00 5366.27 9804.09 4509.77 -8705.34 0.91 0.42 0.84 07-DEC-01 MWD 12311.00 73.40 298.40 94.00 5393.12 9894.16 4552.82 -8784.47 0.31 0.00 -0.32 07-DEC-01 MWD 12403.00 73.50 299.40 92.00 5419.33 9982.33 4595.44 -8861.68 1.05 0.11 1.09 07-DEC-01 MWD 12497.00 73.10 298.70 94.00 5446.34 10072.33 4639.16 -8940.39 0.83 -0.43 -0.74 07-DEC-01 MWD 12589.00 73.50 298.70 92.00 5472.78 10160.43 4681 .48 -9017.68 0.43 0.43 0.00 07-DEC-01 MWD 12684.00 73.30 298.40 95.00 5499.92 10251.46 4724.99 -9097.65 0.37 -0.21 -0.32 08-DEC-01 MWD 12779.00 73.20 298.00 95.00 5527.30 10342.42 4767.97 -9177.82 0.42 -0.11 -0.42 08-DEC-01 MWD 12872.00 73.20 298.40 93.00 5554.18 10431.44 4810.05 -9256.28 0.41 0.00 0.43 '-'-DEC-01 MWD 12966.00 73.10 298.40 94.00 5581 .43 10521.40 4852.83 -9335.42 0.11 -0.11 0.00 08-DEC-01 MWD 13058.00 73.30 299.10 92.00 5608.02 10609.45 4895.20 -9412.64 0.76 0.22 0.76 09-DEC-01 MWD 13152.00 73.50 298.80 94.00 5634.87 10699.51 4938.80 -9491.46 0.37 0.21 -0.32 09-DEC-01 MWD 13247.00 73.30 298.10 95.00 5662.01 10790.54 4982.17 -9571.51 0.74 -0.21 -0.74 09-DEC-01 MWD 13341.00 73.30 297.60 94.00 5689.02 10880.57 5024.23 -9651.11 0.51 0.00 -0.53 09-DEC-01 MWD 13434.00 73.30 298.10 93.00 5715.75 10969.65 5065.85 -9729.87 0.51 0.00 0.54 09-DEC-01 MWD 13529.00 73.00 298.20 95.00 5743.29 11060.56 5108.74 -9810.04 0.33 -0.32 0.11 09-DEC-01 MWD 13622.00 73.30 298.30 93.00 5770.24 11149.56 5150.87 -9888.45 0.34 0.32 0.11 09-DEC-01 MWD 13717.00 73.20 298.80 95.00 5797.62 11240.52 5194.35 -9968.35 0.51 -0.11 0.53 10-DEC-01 MWD 13810.00 73.40 298.00 93.00 5824.35 11329.58 5236.71 -10046.71 0.85 0.22 -0.86 10-DEC-01 MWD 13903.00 73.10 297.00 93.00 5851.15 11418.64 5277.83 -10125.70 1.08 -0.32 -1.08 10-DEC-01 MWD 13998.00 73.20 296.90 95.00 5878.69 11509.55 5319.04 -10206.75 0.15 0.11 -0.11 Comment Depths Measured From: RKB ~ MSL 0 SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER Field KENAI PENINSULA BHI Rep. T WRIGHT 7 01 9 Page _ ~i ;¡ ::) JJ¡ -" j,1 0.90 1.05 0.42 0.72 0.32 -0.32 0.11 -0.21 -0.37 0.63 -0.65 0.85 -0.53 -2.04 -0.42 -0.42 -0.21 -0.63 1.83 0.53 -0.54 -0.65 1.18 Walk Rate Right (+) Left (-) -0.21 0.00 -0.32 0.10 0.11 -0.49 -0.36 0.32 0.53 -0.42 -0.32 0.00 -0.22 0.32 -0.22 0.00 0.53 -0.11 0.22 0.21 -0.33 0.53 -0.53 0.43 Build Rate Build (+) Drop (-) 0.00 1.06 0.41 0.87 0.23 0.61 0.78 0.44 1.14 0.66 0.64 0.70 0.97 0.74 2.00 0.66 0.58 0.37 0.61 1.76 0.60 0.56 0.31 0.54 DL (Per 100 FT) 0.20 -11989.15 -12070.79 -12229.18 -10764.56 -10844.28 -10926.71 -11009.43 -11092.21 -11175.18 -11256.01 -11336.99 -11416.26 -11496.63 -11578.90 -11660.46 -11730.83 -11826.87 -11907.81 E(+) IW(-) (FT) -10288.78 -10367.91 -10446.03 -10526.78 -10604.96 -10684.82 6191 .90 6234.04 6319.50 6151.17 5801.42 5838.85 5878.26 5916.84 5955.26 5994.41 6033.14 6066.18 6111.78 5566.38 5608.33 5648.17 5687.31 5725.88 5763.95 5483.93 5524.63 5441 .90 5401 .23 N(+) I S(-) (FT) 5360.48 Total Coordinate Grid Correction 0.000 Magn. Declination 20.310 Magn. to Map Corr. 20.310 Sidetrack No. j1 2209.43 -1545.72 297.55 11601.45 11690.45 11778.53 11869.57 11957.71 12047.81 12137.92 12227.02 12318.21 12409.39 12500.39 12591 .29 12680.26 12770.28 12858.42 12947.44 13038.49 13128.71 13206.39 13312.63 13402.61 13493.56 13585.44 13765.39 Vertical Section SURVEY DATA 6469:24 6497.07 6551.41 6441.86 6120.04 6146.38 6173.28 6200.42 6227.15 6254.08 6280.37 6307.09 6333.99 6360.14 6382.87 6414.77 TVD (FT) 5906.44 5933.39 5959.99 5987.13 6013.49 6040.26 6067.04 6093.61 95.00 96.00 188.00 94.00 94.00 92.00 93.00 95.00 94.00 81.00 111 .00 95.00 93.00 95.00 95.00 95.00 93.00 94.00 94.00 95.00 92.00 93.00 92.00 Course Length (FT) 96.00 294.00 295.70 296.20 295.70 295.40 295.50 295.30 295.00 295.80 296.10 297.10 297.50 299.20 297.20 297.80 297.20 298.00 297.50 295.60 295.20 294.80 294.60 297.80 Hole Direction (DO) 296.70 Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. WELL DATA Rig Contractor & No. Nabors Alaska DrIng - rig: #273 Survey Section Name HANSEN #1 MWD ~-~ ~ --~~ Job No. 0450-00106 I I t \ i LJ L-J. ¡---Î ~¡1 __~_J1 ~__jj SURVEY CALCULATION AND FIELD WORKSHEET L._ J r'~~l L"J ~ IIV.~ 19-DEC-01 MWD 16069.00 73.10 19-DEC-01 MWD 16165.00 73.20 20-DEC-01 MWD 16353.00 73.20 I v-DEC-01 MWD 14187.00 73.10 11-DEC-01 MWD 14279.00 73.30 11-DEC-01 MWD 14374.00 73.50 11-DEC-01 MWD 14466.00 73.20 11-DEC-01 MWD 14560.00 73.70 11-DEC-01 MWD 14654.00 73.20 12-DEC-01 MWD 14747.00 73.60 12-DEC-01 MWD 14842.00 74.10 12-DEC-01 MWD 14937.00 73.70 12-DEC-01 MWD 15032.00 73.40 13-DEC-01 MWD 15127.00 73.40 ,A;3-DEC-01 MWD 15220.00 73.20 13-DEC-01 MWD 15314.00 73.50 14-DEC-01 MWD 15406.00 73.30 14-DEC-01 MWD 15499.00 73.30 15-DEC-01 MWD 15594.00 73.80 15-DEC-01 MWD 15688.00 73.90 15-DEC-01 MWD 15769.00 73.50 18-DEC-01 MWD 15880.00 73.10 19-DEC-01 MWD 15974.00 73.40 Incl. Angle (DO) 73.20 Survey Depth (Fl) 14094.00 Survey Tool Type MWD "'-"DEC-01 Date (DO) Target TVD Target Description Target Direction (FT) Company PHILLIPS ALASKA, INC. Well Name & No. HANSEN #1 Comment Depths Measured From: RKB ~ MSLO SSO Calculation Method MINIMUM CURVATURE Map North to: OTHER Field KENAI PENINSULA BHI Rep. T WRIGHT of 9 8 Page LJi .~...J.\ ~·d ~ f.- 0.00 -1.08 1.89 0.85 0.74 0.33 0.42 0.75 0.00 1.16 -0.44 0.43 0.00 0.51 0.44 0.31 0.18 -0.32 0.00 -0.51 0.63 0.65 0.75 Walk Rate Right (+) Left (-) 0.21 0.00 0.66 -0.41 -1.54 -0.43 -0.68 -0.89 -0.93 0.00 0.63 0.22 -0.75 -0.52 -0.74 -0.87 -1.05 -0.35 -0.53 -0.83 -0.21 -1.02 Build Rate Build (+) Drop (-) 0.11 -0.11 -1.61 DL (Per 100 FT) 0.23 0.63 1.77 1.72 0.95 0.66 1.72 0.80 0.92 1.12 0.00 1.24 0.46 0.85 0.52 1.00 0.60 0.83 0.83 0.98 0.97 0.39 0.64 1.13 Grid Correction 0.000 Magn. Declination 20.310 Magn. to Map Corr. 20.310 Sidetrack No. ~---1' -13830.56 -13895.45 -13764.86 -13712.38 -13196.56 -13269.07 -13344.20 -1 3417.17 -13487.02 -13558.35 -13627.32 -12753.70 -12782.70 -12830.05 -12901.72 -12978.22 -13051.22 -13125.49 -12677.10 E(+) I W(-) (FT) -12307.67 -12384.20 -12460.72 -12537.98 -12585.78 6628.52 6645.88 6674.38 6718.13 6765.47 6810.90 6858.13 6903.94 6950.66 6999.45 7047.47 7094.32 7142.79 7190.64 7251.53 7290.79 7340.30 7388.31 6582.40 N(+) I S(-) (FT) 6363.55 6407.20 6452.00 6498.43 6527.32 Total Coordinate 13943.40 14031.96 14121.94 14177.68 14284.13 14373.37 14407.11 14462.27 14546.04 14635.77 14721.51 14809.20 14893.40 14979.29 15068.47 15155.38 15238.98 15324.63 15407.91 15511 .49 15576.19 15657.33 15737.07 13855.36 Vertical Section SURVEY DATA 6888.67 6924.41 6958.06 6992.82 7030.02 7067.37 7104.64 7144.49 7184.52 7236.91 7271.25 7314.63 7356.65 6751.51 6763.91 6784.57 6816.97 6853.23 TVD (FT) 6578.50 6605.01 6633.06 6663.04 6682.06 6719.40 91.00 93.00 74.00 97.00 95.00 92.00 95.00 93.00 117.00 91.00 93.00 93.00 95.00 95.00 36.00 59.00 90.00 97.00 113.00 92.00 93.00 95.00 59.00 Course Length (FT) 94.00 307.50 306.50 306.50 304.00 304.40 305.10 306.10 303.00 303.70 302.60 303.00 300.90 300.90 301 .20 301 .60 301 .90 301 .90 303.00 301 .00 301 .20 301.30 Hole Direction (DO) 299.40 300.00 300.70 Target Coord. NIS Slot Coord. NIS 2209.43 Target Coord. E/W Slot Coord. E/W -1545.72 Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 297.55 WELL DATA Rig Contractor & No. Nabors Alaska Dring - rig: #273 Survey Section Name HANSEN #1 MWD ~_ ~ r Job No. 0450-00106 ;v.J.' ~- ~ ; -DEC-01 MWD 17464.00 68.20 31-DEC-01 MWD 17555.00 68.40 31-DEC-01 MWD 17648.00 67.70 01-JAN-02 MWD 17745.00 67.20 01-JAN-02 MWD 17840.00 66.50 01-JAN-02 MWD 17932.00 65.70 01-JAN-02 MWD 18027.00 64.70 04-JAN-02 MWD 18120.00 64.30 04-JAN-02 MWD 18237.00 6250 04-JAN-02 MWD 18311.00 62.20 05-JAN-02 MWD 18404.00 62.20 05-JAN-02 MWD 18495.00 62.80 21-DEC-01 MWD 16539.00 73.20 21-DEC-01 MWD 16632.00 71.70 21-DEC-01 MWD 16727.00 71.50 22-DEC-01 MWD 16786.00 70.90 30-DEG-01 MWD 16899.00 70.50 30-DEC-01 MWD 16994.00 70.00 30-DEC-01 MWD 17030.00 69.70 30-DEC-01 MWD 17089.00 69.30 30-DEC-01 MWD 17179.00 68.50 31-DEC-01 MWD 17276.00 67.60 31-DEC-01 MWD 17369.00 67.60 Incl. Angle (DO) 73.30 Survey Tool Type MWD DEC-01 Survey Depth (FT) 16447.00 .- Date (DO) Target TVD Target Description Target Direction (FT) LJ LJ l J ~. I-..-f' ~~ .~ .~ .---f SURVEY CALCULATION AND FIELD WORKSHEET LJ ..--.1. ~~ ~ 'IV,~ Company PHILLIPS ALASKA, INC. Well Name & No. HANSEN #1 ,'-' Projected Data - NO SURVEY Comment Survey Survey Inc\. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Build (+) Right (+) Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 F1) Drop (-) Left (-) '-·JAN-02 MWD 18532.00 62.90 306.80 37.00 7373.53 15769.58 7407.96 -13921.86 0.77 0.27 0.81 05-JAN-02 MWD 18630.00 62.90 306.80 98.00 7418.18 15855.69 7460.22 -13991.72 0.00 0.00 0.00 SURVEY DATA Depths Measured From: RKB g] MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER Grid Correction 0.000 Magn. Declination 20.310 Magn. to Map Corr. 20.310 2209.43 -1545.72 297.55 Target Coord. NIS Slot Coord. NIS Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 1 OOft~ 30mD 10mD Vert. Sec. Azim. (DO) (FT) Target TVD Target Description Target Direction WELL DATA Field KENAI PENINSULA BHI Rep. T WRIGHT Rig Contractor & No. Nabors Alaska Dring - rig: #273 Survey Section Name HANSEN #1 MWD Company PHILLIPS ALASKA, INC. Well Name & No. HANSEN #1 LJ = IIV.~ ",,--l '_I _.1- ~--~.i .. åJ " ~_& Job No. 0450-00106 Sidetrack No. Page 9 oi 9 l ---Ì LJ L-J L....j L---..i . _:: ~ '----.J' .----i' SURVEY CALCULATION AND FIELD WORKSHEET ~ R"""'·E"'""'(~:CjVE·· ·['l, ~ 1,:'" . 4PR 0..3 ?O'O'I ;:, -.~ "- ...1 AIiska 011 & ~ Cor./i. t.;c1l/nliBsion ~~ 1-)4I1~ r Ca~¿ W:""'7iPV . · . LbI"'Y cF ?ß$?& ~/ ðF :at<dø/E fi,(J7' SR'r @ /68eo ' /fq:) ~ 71 Z 77ID 0( . 1m "RS ~ .-:?ð #~A!.(."h- ~ J444# ß~ ;?63-~/4() rþ#1. ¡/1I-ß-¿/z5 275 //",9N5~ ~ / -¿ () I I 57 ~·/ð /#tVllP"v .4vßE~i 04/23/2003 02:15 253314~ ) HANSEN 1 ) PAGE 01 ."", #- "'''' ""'./ . ··:·;~·::·>~~:~:~[fgr~:~{~~F~?~f~f??-:'f~?~~~~~~f~~tP?~f~s1~7r~~~1rY~:~:~····' - ~ .-. - --...-..~ .-_:;-o:_~~~~~~~t~t-:}:~ .~~.--~:--~~:;:.:-:-~~.~. - _. ~ . ..0 "_ .. .. 0'_ '. /.--..-. - . .- -.. ,.:-.:.:"::',",.'. '::.,"' "',.'. " # 1 ., #"_# '",.", .# . . I.., . #' #' ,. -' '## .'.", " '.'- "'-' . . " (S) .p.. . . ... . - ~ .......... . .".", ",.' -"' .- ".- ,. " ::~: ..t;3 '0 . . ... - - - - ; '-.. -0- .-"--..- - .... . - __ 0 ...._.. ._.. _. . .. . ,.. ...--;... -.- .....:__.j_.-:_:...~_'!..~:... . -" ..' .. uT::';;.._.h ,. ",_.~'_-'~" ...,'. N . ·wz;c,~. .~. .....)~;ii~1tfC..:.·..·,:~.::;·.·....·,,··.t;~~ì\·;'.i;.~,~~iJ~~t·:·E;';i:,~~~,~iX,\{·;~~f~~t;;:~.·· : .. .. 0_·· . -... -".- . , h .. -. - 0-_·-:"0 :. 'ßO -. . . . #. -~ - - .. . .". - . O· ..." . . . - - . . - -- - . . - ."-... - - __ :'.--.'.._-0_._-'.-- .._ _..... .~ _ 0_ ._- _.... 0 -_... - _ . _ . - - -- . .- . - .. O· .- ..'- .. 4- .. . . .. . ..- -'. -,. , . . . .. ...... .0-_.....· ~,.,' ':', , . . ~~\~ ~. .. ConocoPhillips Alaska, Incorporated (CPA) recently requested approval to resume annular disposal at Hansen # 1. They have also requested approval to increase the total volume of fluids disposed in the well. The Hansen # 1 well has a surface location approximately 500 feet in-shore of Cook Inlet. The disposal interval is located at a subsea depth of 3500 feet, approximately 0.4 Annular disposal is one of the most effective and environmentally preferable methods for dealing with wastes generated during the drilling of a well. There have been numerous examples of successful annular disposal in wells at both onshore and offshore locations throughout Alaska. The AOGCC provides the opportunity for annular disposal and evaluates each proposal on its merits through its regulatory requirements imposed on an operator. Before any annular disposal is approved, a determination is made that the well is properly constructed and that it does not serve as a conduit for fluid migration out of the intended disposal zone. Your letter to the Alaska Oil and Gas Conservation Commission ("Commission") dated October 10,2002, expressed concerns about annular disposal operations in the Cook Inlet. An ongoing subsea release at the Unocal-operated King Salmon platform, traced to annular disposal into Well K-19, was the basis for your letter. In it, you recommend the AOGCC "suspend future permitting of annular disposal operations in Cook Inlet" until plans to deal with releases similar to that at King Salmon can be developed. Dear Mr Carter, Mr. James E. Carter, Sr. Cook Inlet Regional Citizens Advisory Committee 910 Highland Avenue Kenai, AK 99611 !Æ~!Æ~~~!Æ AI,ASKA. OIL AND GAS CONSERVAnONCO~SSION February 28. 2003 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~T!Æ~¡ Jt ) FRANK H. MURKOWSKI, GOVERNOR JR\RR\jc Paul Mazzolini, Drilling Team Leader ConocoPhillips Captain Ronald J. Morris, USCG Mr. Gary B. Folley, ADEC cc The Commission appreciates your interest disposal. Please contact Mr. Tom Maunder about the Hansen #1 plans. Sincerely, ~ f~/4dZ ~andY ~uedrich Commissioner and concerns regarding annular should you have any questions The AOGCC has approved the CPA request. Our review addressed both the wellbore and a calculated zone of influence for the proposed disposal fluid; we have reviewed a comprehensive set of data that includes well logs, temperature logs, available seismic, and the annular disposal results to date. The increased volume of fluids to be disposed in the annulus of Hansen # 1 should not represent any increased potential for fluid migration. Please note that there are a number of conditions that have been applied to the Hansen well approval. The conditions are designed to ensure all activities are done with best oilfield practice, are monitored for early indications of problems, and the results are communicated with the AOGCC for review and analysis. miles offshore. The original well was drilled during 2001-02 and thus far 68,000 barrels of fluids were successfully pumped into the well annulus under an AOGCC approval. The basis for the current CPA request includes the following: - planned plug back and sidetrack of the original well to further evaluate the field potential; there are no economic alternatives available for the disposal of drilling wastes underground; successful performance of annular disposal operations into the well has been demonstrated; favorable geologic conditions, including a suitable receiving zone for fluid disposal, confinement of fluids, and demonstrated mechanical integrity of the well. Mr. James E. Carter, February 28, 2003 Page 2of2 ) Sr. .\ " ) ) Paul Mazzolini Exploration T earn Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 February 19, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Hansen #1 Application for Sundry Approval (201-157) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to correct the surface location for the Hansen #1 well. If you have any questions regarding this matter, please contact me at 263-4603 or Scott Reynolds at 265-6253. " FJÞ-. ~",JL- Þ1.Jt1.WL-vv' P. Mazzolini Exploration Team Leader CPAI Drilling PM/SR/skad ,- -: Form 0-403 Rev 06/15/88 RSOMS BFL ß~¿ FFR 9 2003 SUBMIT IN TRIPLICATE ~ Approved by order of the Commission Conditions of approval: Notify Commission so Plug integrity _ Mechanical Integrity Test ß-c-<-//t'~ .-:z- FOR COMMISSION USE ONLY representative may witness BOP Test Location clearance Subsequent fomu.equired 0- Commissioner l Approval no. "''''''!è ''l \,-S\ \\: "J 2/1 '/~~te ~¿~3 (~5Y Name of approver 7. I hereby certify that the foregoing is true and correct Signed p~tÞ~vJ1L- Date Z. - tq· 2.00~ Prepared by Sharon Allsup-Drake F-L ~h'L- /1A z;z,D 1..-11'I Date approved Service _ to the best of my knowledge. Title: Exploration Drilling Team Leader Questions? Call Scott Reynolds 265-6253 14. Estimated date for February 22, 2003 commencing operation Oil No SSSV Description summary of proposal Refer to attached morning drilling report for LOT test, surface cement details and casing detail 5. Status of well classification as: Gas Suspended BOP sketch _ sheets, schematic 3. Attachments Detailed operations program _ Packers & SSSV type & measured depth) SAB packer @ 6525', SAB packer @ 17502' Tubing (size, grade, and measured depth 3.5", L-80 @ 5443' 11' ! Perforation depth: rue vertical measured 7098' 7915' 6958'. 6924' 7555' 17465' 6742' 6965' Intermediate Production 6825' 8630' 9.625" 7" Surface 5177' 3.375" Conductor Casing Structural 698' Length 93' 20" Size 30" Cemented Driven 488 sx Class G lead & 315 sx Class G tail 386 sx 12.5 ppg Class G, 504 sx 15.8 ppg Class G, 96 sx G Neat 116 sx Class G, 474 sx 15.8# Clas 72 sx LiteCrete 16823' 18622' 6693' 7418' 5175' 3340' 696' Measured Depth 93' 696' True vertical Depth 93' Effective depth: 2. Present well condition summary Total depth: measured rue vertical measured true vertical 18630 7418 feet feet feet feet Junk (measured) PRN plug @ 16567' & Baker N-1 CIBP @ 7544' 16450' 9001 FNL, 307' FEL, Sec. 33, T3S, R15W. SM (asp: Plugs (measured) 155036,2152496) At total depth At effective depth (as proposed) At top of productive interval 641 1750' FNL, FWL, Sec. 33, T3S, R15W. SM Hansen #1 Permit number / 201-157 O. API number 50-231-20010-00 11. Field / Pool Exploration 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2148' FSL, 527' FEL, Sec. 2, T4S, R15W. SM 9. Cosmopolitan Project 8. Well number approval number 2. Name of Operator ConocoPhillips Alaska, Inc. . , , Type of request: Abandon _ Alter casing _ Change approved program _ APPLICATION FOR SUNDRY APPROVALS Re-enter suspended well Time extension _ Stimulate _ Variance _ Perforate _ 6. Datum elevation (OF or KB 163' RKB feet 7. Unit or Suspend _ Repair well Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service _ Property name feet) ) \ I STATE OF ALASKA .) ALASKA OIL AND GAS CONSERVATION COMMISSION 4/l~ DLf ¥/1 ~ ¿. 1(11 (7:> Other _X Correct Surface Location 4 SHEET !<OR l. SCAU:" - )00" 'oÐI'. 5COU "/A oonoc. 01(). (1)097 OC:CX[D lIT COlA" IN PCO t ~: \T ~! II h l.! hê ~ð J ì~: ~.- u i~ r I .> i! ul < 0 -=j ~: ('Q:f: 0- .:.:~ æ: ~~ m! <~ 8 s (/)~ < i 5!:~ ~ I ~f ~l J: D..~ 0.< ""': ~ -ii ~ I § ~ t:! ~ )I: ~ I!$ ~ '" .. ( ~ ~ ~ ~ J (e ~OI'" IlEtaoI> 'OVICJ FOUND GlO BRASS CAPPED r 1oI000000ENT. 1918 SEC, 2 j SEC. 1 SEC. 11 SEe. 12 ,. NOTPI IJ ~TAL OAtuW IAS[D Of US STATl: Pl-'H( ~1tS In7, ALASKA ZOf£ 4. -..ENT US[I) FOIl BASIS aT COOIIDfIAIt$ wAS HC:S IOOIIIMEHT "I!OI, COOII»IA TES fOIl !>IS -...Ð<T tÐIE [ST AIIU$H[D IN !HE STATE aT AlASKA DÐ'NmIDIT f6 _TAtIO< NÐ PUIIUC 'AOUIIES C£OR£FDIЫ»OÇ PROLCT PHASE I NIO I. 2J ~ _ IÐI£O'f AIOf: QI!IO. IIASIS f6 IIEAMOÇS IS ITOOW . STAIIC CPS IIASIEl.M: tllS[JlVATIO<. JJ YÐ!1ICAI. DA1UII IS IAS[D 01 "AW lie DA1\.OI. IoIOU«JtT US[I) FOIl BASIS (T £l£VA_ w.s HC:S UOIUÆHT " 116 ([l[V.-IeG.SO·) 4) SECTIOH l..::s _ I£R[GIH All( IIASED 01 DATA aT RUaIII. 5J SLRYEY CO>tDUC1tD IN -.- 1:OISJ.1'OOC c;ACUP - - AUCUST 27. 2001 I1<ROUCH SEl'1D&II 01, 2001. ~3 i~ ~ ,,..---- -.....-., I HANSFN NO. 1 , DRIWNG P.4.D I , I J ,----.. I HAHSÐ< "0. I IO£UH£AO 1 / l' ' GR>O ": 21«659..501 ,.. / 'r I ~~~6~'~008· , lOHQtUO£, 15"411'05-120" I EI.EV.~":5.I· (GROUND. YElJ.) ( \ , ,r\ I I · I \ ,I 1527 m L í \,~ I -----~--' ~~ .1 ~~~'-'I " I \1 , , h \\ \\ \L-=======-~ -- \\ \\ \\ \' }; 1/ 1/ " 1/ 1/ II II II 1/ 1/ ( ( \\ \ \ \ \ II " } 1/ II H&"2TOO"W SECTION UHf SEC1ION 2. TOVINSHlP 4~, RmGE 15 \It£ST'. s.w., AL4SI<A 2148' FSl ~ ,-. I / ; ,/ ~ : § ~J ~/ ð/ .. I R/ I I I I J / / / I / / " of 1 2/19/2003 9 :21 AM r Tom Maunder <tom maunder@admln.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission > > > > > Name: Annular Disposal Record ver 1.4.xls Annular Disposal Record ver 1.4.xls Type: EXCEL File (application/msexcel) Encoding: base64 > Please Note the new email address Below > > Scott D Reynolds > Drilling Engineer, Exploration > (907) 265-6253 OFFICE > (907) 240-5660 CELL > Scott. D.Reynolds@ConocoPhillips.com > > (See attached file: Annular Disposal Record ver 1.4.xls) > > Tom- > > For Hansen, we will be running our annular disposal operation similar to > our other operations on the slope. The plan is to hold cuttings and > fluids in the grind and inject facility until it nears capacity; > thereafter, we will dispose of the stored fluids in a batch of > approximately 300 bbls fol/owed by approximately 350 bbls of water flush. > After the flush, the surface lines, and annulus will be freeze protected > with diesel. We will only pump enough diesel to freeze protect the annulus > down to 2000' TVD. Attached is our Annular Disposal Log used by aI/ CPAI > drilling opertions in Alaska that have annular disposal operations as part > of their drilling program. Scott Scott, Thanks for the info. I am surprised with regard to the freeze protection. I understand that on the slope and I maybe can see for surface lines and the top 100' of the well or so, but to 2000' TVD seems a bit much. Am I missing something here?? Also, if you are disposing while conducting drilling operations the wellbore ought to be warmed up due to circulating the warm mud. I would appreciate your thoughts on this. Tom Maunder o Reynolds wrote: Subject: Re: Hansen Annular Disposal Date: Wed, 19 Feb 2003 09:11 :37 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Scott D Reynolds <Scott.D.Reynolds@conocophillips.com> Re: Hansen Annular Disposal ) RIG #: I DISPOSING INTO ANNULUS OF WELL: I ORIGIN OF FLUIDS START TIME END TIME rIGHT DISPOSAL SUPERVISOR: VERSION 1.4 PUMP RATE (BPM) STATIC PRESSURE (PSI) DISPOSAL PRESSURE (PSI) CPAI - DAILY ANNULAR DISPOSAL RECORD BARRELS DISPOSED (List under proper fluid type) Operation that generated Waste Mud Mud WATER for Flushing Annulus MUD WATER TOTAL VOLUMES FOR DA Y: I ADDITIVES USED: GEL NIGHTS DAYS IDA Y DISPOSAL SUPERVISOR: DIESEL for Freeze Protecting Rig Wash Water DIESEL WASH WA TER Q-GEL X-TND CPAI DAILY ANNULAR DISPOSAL RECORD DA TE: OTHER (specify in comments) OTHER BICARB TOTAL CUMULATIVE VOLUME Total for Today PH6 1800 TO 1800 HRS FOR MUD ONLY: WEIGHT (PPG) FUNNEL VISCOSITY Cummulative Total from Previous Day I ConocoPhillips SUPERVISOR: Page_ of_ / COMMENTS - l New Total for this Annulus SCOTT D. REYNOLDS 02-19-03 In this request, PPCo has requested a further increase in the allowed disposal volume to 140,000 bbls. PPCo has provided a table listing the potential additional wastes to be disposed. The original request (302-006) had authorized a disposal volume of 75,000 bbls and thus far PPCo has disposed of nearly 68,000 bbls. PPCo lists several reasons for this reactivation request in their application. PPCo has very limited other waste disposal options with no other on-shore activities in South Alaska. While they do have a Class II disposal well on the NCIU platform, the logistics of transporting the waste overland and water presents opportunities for spills and environmental damage that do not exist when the disposal is done at the well site. PPCo has two waste storage pits at the location. These pits were developed according to DEC permits to contain the water base and oil base hole section wastes. According to PPCo, the cuttings in During the past year, PPCo has disposed of nearly 68,000 bbls of drilling waste and accumulated rain water/snow melt. A condition of increasing the allowable EMW at the shoe was to conduct a temperature survey after initiating disposal at higher surface pressures. The temperature surveys demonstrated that the drilling waste was being accepted by formations below the shoe. The application indicates that the surface disposal pressures experienced have not demonstrated a decrease that would indicate that fluids are moving to shallower horizons. Rates up to 2.5 bpm have been employed. Continued operations with a that maximum allowed rate of 2.5 bpm should insure that the emplace drilling waste will be contained within the receiving formations and not migrate to shallower strata. As operations are resumed, it would be appropriate for PPCo to conduct another temperature survey to demonstrate that the disposed fluids are being accepted by formations below the shoe. The prior "notes to file," relating to sundry approvals 302-006 and 302-224 are incorporated by reference for this discussion PPCo has submitted a sundry application requesting approval to resume annular disposal into the Hansen #1 (201-157) and to increase the authorized disposal volume. They have made this request since they have also applied to sidetrack the well as the Hansen #1 A. PPCo previously had obtained approval to dispose of drilling waste into the 9-5/8" x 13-3/8" annulus when the well was originally drilled (302-006). That approval also authorized PPCo to dispose of up to 75,000 bbl of drilling waste and rain water/snow melt. A subsequent approval (302-224) was given to exceed the EMW at the surface casing shoe as specified in the original approval. Request to Resume Annular PPCo Hansen #1A.. .203-004.. .303-004 PPCo Hansen #1.. .201-157 Disposa ) NOTE TO FILE } Æ Tom Maunaer, PE Sr. Petr Engineer ;J-/( ~ -- a -S 8 9 6 3 4 5 7 Approval for PPCo's request to resume annular disposal 13-3/8" annulus of the Hansen #1 is recommended. PPCo's request to exceed the previously established 14.3 the surface casing shoe of Hansen #1 is affirmed. (302-224) The disposal rate shall not exceed 2.5 bpm. The surface pressure while pumping may not exceed 1500 psi. (302-224) After resuming disposal at the higher-pressure conditions, PPCo shall run temperature logs to confirm where the waste is being placed and provide this log to the Commission. These logging runs should include a base pass preferably conducted prior to resuming disposal and follow up pass(es) after disposal is underway. The logs should be run as deep as practical to potentially identify the waste-receiving zone(s). PPCo shall monitor the surface pumping pressure at all times while disposal is occurring and cease disposal operations if the pressure information indicates that the waste is not being confined below the shoe. PPCo shall maintain a log of their disposal operations noting the volumes of waste disposed, the weight of the slurry pumped and representative surface pressures while pumping different fluids (ie clear water or slurry). The disposal volume is increased to 140,000 bbls. Except as modified the remaining conditions of approval 302-006 still apply. 302-224 and 2 EMW mit at 1 nto the 9-5/8" x Based on this analysis the oil base pit were removed and processed during the last year. Cuttings remain in the water based pit. In addition, rainwater and snowmelt have also accumulated in both pits. By far, the greatest volume of waste to be handled is the precipitation that has fallen since disposal was halted in October 2002. 25.080 (h)(1) lists reserve pit fluids as a drilling waste allowable for disposal. No distinction is made with regard to precipitation that might accumulate in a cuttings pit. ) the following is recommended of3 Scott, Thanks for the info. 1 am surprised with regard to the freeze protection. 1 understand that on the slope and 1 maybe can see for surface lines and the top 100' of the well or so, but to 2000' TVD seems a bit much. Am 1 missing something here?? Also, if you are disposing while conducting drilling operations the wellbore ought to 2/19/2003 :5 AM Subject: Re: Hansen Annular Disposal Date: Wed, 19 Feb 2003 09: 11:37 -0900 From: Tom Maunder <tom _ maunder@admin.state.ak.us> To: Scott D Reynolds <Scott.D.Reynolds@conocophillips.com> References: <OF621 AA25C.8087BC89-0N89256CD2.005E53AE@ppco.com> Here is my note to Scott. Tom Maunder wrote: Jim Regg At a minimum, we should investigate the ZOI from injecting 60,000+ bbls of fluid to date, and should also evaluate the new ZOI from an increase to 140,000 bbls injected. We might also consider investigating shallow seismic data (if it exists) in the likely ZOI as we did for King Salmon (K-19). These precautions are warranted given the contentious nature of annular disposal operations and 1 believe would be the additional support for our decision to approve the significant increase of waste volume disposed in the annulus of Hansen #1. Both CIRCAC and USCG are on record as opposing annular disposal without some ability to remedy a King Salmon-like leak; their concerns were raised in reference to offshore ops. 1 anticipate at least CIRCAC will raise concerns despite the fact that Hansen is onshore when they learn of the AOGCC approval. (of course, they would have to be aware of the practice first; we should be open and honest with them about our approval -- 1 am drafting a letter to CIRCAC with copies to USCG and ADEC to forward our approval). 1 have looked over the Hansen annular disposal sundry. Your analysis is excellent and you have identified appropriate requirements to assure the well bore does not serve as a communication path for fluids out of the intended zone (and ultimately to surface). Based on infonnation provided, CPA appears to have taken extraordinary measures (ref: 9/4/02 letter) to address fluid handling (prevent misinjection) and to ensure well integrity (ref: sundry application). My concern is that we have only confinned the existing integrity of the wellbore. 1 do not see any anaylsis of a zone of influence (ZOI) and am concerned that the same problems that are suspect led to King Salmon fluid-to-surface could also occur here. Tom Subject: Re: [Fwd: Hansen Annular Disposal] Date: Wed, 19 Feb 2003 11 :47:47 -0900 From: Jim Regg <jim_regg@admin.state.ak.us> Organization: AOGCC To: Tom Maunder <tom _ maunder@admin.state.ak.us> Re: [Fwd: Hansen Annular Disposal] ) ) 20f3 USA Additional Information: Last Name Maunder 2/19/2003 :5 AM Tom Maunder Sr. Petroleum Engineer <tom _ maunder@admin.state.ak.us> Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Suite 100 Cellular: 907-244-1567 Anchorage AK 99501 Fax: 907276-7542 Work: 907 793-1250 Conference Software Address Tom Maunder <tom _ maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission > > > > > Name: Annular Disposal Record ver 1A.xls Annular Disposal Record ver 1A.xls Type: EXCEL File (applicationlmsexcel) Encoding: base64 > Scott D Reynolds > Drilling Engineer, Exploration > (907) 265-6253 OFFICE > (907) 240-5660 CELL > Scott.D .Reynolds@ConocoPhillips.com > (See attached file: Annular Disposal > > Please Note > the new em ail address Below Record ver 1.4.xls) > For Hansen, we will be running our annular disposal operation similar to > our other operations on the slope. The plan is to hold cuttings and > fluids in the grind and inject facility until it nears capacity; > thereafter, we will dispose of the stored fluids in a batch of > approximately 300 bbls followed by approximately 350 bbls of water flush. > After the flush, the surface lines, and annulus will be freeze protected > with diesel. We will only pump enough diesel to freeze protect the annulus > down to 2000' TVD. Attached is our Annular Disposal Log used by all CP AI > drilling opertions in Alaska that have annular disposal operations as part > of their drilling program. > > Tom- > Scott be wanned up due to circulating the warm mud. this. Tom Maunder D Reynolds wrote: Re: [Fwd: Hansen Annular Disposal] ) I would appreciate your thoughts on ) 30f3 Jim Regg <jim regg@adnlin.state.ak.us> Petroleum Engineer AOGCC Administration 2/19/2003 :5 AM 99501 USA Additional Last Name First Name Version Infonnation: Maunder Tom 1 2 Fax: 907 276-7542 Work: 907793-1250 Conference Software Address Tom Maunder Sr. Petroleum Engineer <tom _ maunder@admin.state.ak.us> Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Suite 100 Cellular: 907-244-1567 Anchorage AK Tom Maunder <tom_ maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Re: [Fwd: Hansen Annular Disposal] First Name Tom Version 2.1 ) AJaska OH & Gas, Cons. Commission Ancllor8Çif ~N A t I RECE h ,) 200~~ VED Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon Allsup-Drake Well Files cc RT/skad R. Thomas Greater Kuparuk Team Leader Sincerely, Please call me at 265-6830 should you have any questions Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Dear Commissioner: Re: Annular Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Disposal. Fourth Quarter, 2002 January 10.2003 ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas@ppco.com \ .> '\ Randy Thomas a of -- J 5 --¡ Greater Kuparuk Team Leader Drilling & Wells January 2002 October 2002 Hansen #1 Well Name 472 h(l) Volume 100 h(2) Volume o during thefourth quarter 2002: h(3) Total for Volume Quarter 572 Freeze Protect Volumes o 67224 Previous Total 67796 Hansen # 1 Cook Inlet Annular Disposal New Total Start Date End Date Source Wells December 2001 January 2002 February 2002 } CD2-45 22514 100 o 377 22991 Open, Freeze Protected September 2002 January 2002 CD2-49, CD2-17 CD2-47 26874 100 o 375 27349 Open, Freeze Protected CD2-50, CD2-25 44 CD2-34, CD2-26 CD2-15 31181 100 o 371 31652 Open, Freeze Protected October 2001 March 2002 2P-438 30331 100 o 212 30643 Open, Freeze Protected lC-14 32115 100 o o 32215 Open, Freeze Protected Authorization Expired during the fourth quarter 2002: Freeze Protect Total Volume Fluids Injected Volume 379 CD2-14 Well Name CD2-39 30597 Total h(l) Volume 29466 100 Total h(2) Volume 100 o Total h(3) Volume o 376 31073 29945 Open, Freeze Protected Status of Annulus Open, Freeze Protected October 2001 November 2001 October 2001 December 2001 CD2- March 2002 January 2002 2P-420, 2P-415, 2P-429 IC-I09, CD2-45, CD2-47, CD2- 32, IR-36, I C-24 Sept 2002 CD2-15, CD2-47, CD2- 44 Start Date End Date Source Wells I I Total Volumes into Annulifor which Disposal }' 38-07 3S-18 CD2-34 CD2-48 22895 11281 18155 206 100 100 100 100 o o o o 22995 11381 18255 306 372 375 216 o o o o o 23367 11756 18471 306 Oct 2002 Dec 2002 Dec 2002 Dec 2002 Dec 2002 Dec 2002 Dec 2002 Dec 2002 September 2002 October 2002 CD2-38, CD2-44, CD2-29, CD2-13 CD2-13, CD2-37, CD2-35 CD2-28, CD2-45 38-09,38-14,38-10 38-18 CD2-26 Annular Disposal during the fourth quarter of 2002: h(2) h(3) V olume Volume Well Name 15244 h(l) Volume 100 o 15344 Total for Quarter Freeze Protect Volumes 380 13902 Previous Total 29626 New Total Start Date End Date Source Wells Form Approved by order of the Commission 0-403 Rev 06/15/88 FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity ~t .,.,- ~ ., '- Subseq~t f?r~ required ~<é...« o..\\c,.c:."(.~C OC)<:),\\t)"c.. \ tCf'-.d"\C,,"> Original Signed By Iltr{,Jy I'tuc.chfch PBOMS 8Fl 0- I Approval no. .. -' / .=3 ¿~:3 - ¿;~)7 ~~.~ C\Ô~~~~~:S~~)0~ ~S -"".""'Î SUBMIT IN TRIPLICATE l.~R Commissioner 4 Conditions of approval: ?c 1 f11r ~ ~ J-' Signed Paul Ma~ f.,vOO - ....-..-J (')'/ ., / Date 0 ø:- 03 Prepared by Scott D. Reynolds Title: Drilling Team Leader Name of approver Date approved Service - 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Scott Reynolds 265-6253 Questions? Call 6. If February proposal was verbally approved Oil XX Gas_ Suspended _ 5,2003 4. Estimated date for SAB Packer No SSSV Description summary of proposal I commencing operation 5. Status of well classification as: 13. Attachments Packers & SSSV type & measured depth) @ Detailed operations program _ 6525', SAB Packer @ 17502' BOP sketch _ I~,~aska OH & Gas Cons" Cmnmissiür: L~i1lchorar¡é: Tubing (size, grade, and measured depth 3.5", L-80 @ 5443' ¡),N 0 1 2003 true vertical 7098' 6958', 6924' 6742' RECE VE[) Perforation depth: Production Liner Intermediate measured 5177' 6,825' 8,630' 7915' 9.625" 7" 7555' 17465' 386 sx 12.5 ppg Class G, 504 sx 15.8 ppg Class G, 96 sx G Neat 116 sx Class G, 474 sx 15.8 ppg Class G 72 sx LiteCrete 6965' 6,823' 18,622' 6,693' 7,418' Surface 3.375" 5,175' 3,340' Conductor Casing Structural 696' Length 93' 20" Size 30" Cemented Driven 488 sx Class G Lead & 315 sx Class G tail 696' Measured Depth 93' 696' True vertical Depth 93' Effective depth: ~"II . 307' FEL, condition summary measured true vertical measured true vertical 18,630' 7,418' feet feet feet feet Junk (measured) PRN Plug @ 16567' & Baker N-1 CIBP @ 17544' 16450' At total¡ 900', ''L.., 12. Present well Total depth: Plugs (measured) Sec 33, T3S, R15W. SM (asp's 55036,2152496) At 750' FNL, effective depth At top of productive interval 641' FWL, Sec 33, T3S, R15W SM (as proposed) Hansen #1 9. Permit number I 201-157 API number 50-231-20010-00 Field I Pool 11 Exploration 10. 3. P. 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2148' FSL & 527' FEL, Sec 2, T4S, R15W, SM Name of Operator Phillips Alaska Address O. Box nc 2. ,~ Type ':of request: Abandon _ Alter casing _ Change approved program _ APPLICATION FOR SUNDRY APPROVALS Re-enter suspended well Time extension _ Suspend _ Repair well Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service _ approval number Exploration NPRA 8. Well number Variance _ Peliorate 6. Datum elevation (OF or KB feet) 163 feet Property name RKB 7. Unit or - Stimulate _ Other X Request for Annular Disposal STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ') ~ 2/lr Á-?-h "'1 ,tv.. L4l 21'1 r II:) , 1/2/2003 Scott D Rcynolds ramen #1 A Annular Disposa Sundry.doc Page At the start of disposal operations, the disposal pressure was 1070 psi at a pumping rate of 1.5 barrels per minute. By the end of disposal operations, the disposal pressure ranged from 900 psi to 1200 psi with the 2.5 barrels per minute. This data would indicate that the 13-3/8" x 9-5/8" annulus on the has proven to be a very effective and safe alternative for disposal of drilling wastes. pumping rate at IIansen # 1 well of2 l'he only alternatives to annular disposal at lIansen #1 are transporting the fluid waste to a Class II Disposal well on the Tyonek Platform or Class II Disposal wells in Kuparuk. The cuttings would have to be excavated from the lined pits and transported to a f,rrind and inject facility on the Tyonek Platform or the North Slope for disposal. This method of disposal wOlùd not only by costly, there would also be an increased risk of exposing the environment to potential spills while trucking and boating the waste to an off site Class II Disposal Well. Truck traffic on the Kenai Peninsula would also be increased significantly. Rationale for Continued Disposal 'Tcmperature log LWD GR/RES in the 12-1/4" Mud l..ogs :t\laska Oil & Gas Cons li,"(~h0ra(Je Ä.N 0 7· 2003 ûormnìssw¡ The following logs USI'Tlog Hole. RECE VED have been flm to date: History of Operations The total permitted disposal volume is 75,000 bbls on October 1, 2002, a total of 67,796 bbls disposed via the annlùus. of drilling waste. of drilling waste and By the conclusion of disposal operations rainwater accumulation in the lined pits was On :March 11, 2002, CONOCOPHILLIPS Alaska, lne. requested and was granted, approval to COlnmence annlùar disposal into the 13-3/8" x 9-5/8" annulus of I-Jansen #1. CONOCOPHILLlPS Alaska, Inc. is requesting that the aforel'nentioned annlùus be re-opened for disposal of drilling wastes that will be gcnerated during the I-Jansen #lA sidetrack. CONOCOPl:lILLIPS Alaska, Tne. is also requesting to increase the permitted disposal volwl1e to 130,000 bbls to accol11111odate the volwl1e of fluids and cuttings generated during the sidetrack and rain water/ snowl11elt that has accU111ulated in the pit systelll. Dear Commissioner Taylor, Hansen #lA Sundry Notice Re-open Annlùus for Disposal Increase VolU111e of Disposal Reques t to Reques t to of Drilling Waste Re: 333 W 7th Avenue #100 Anchorage, AK 99501-3539 CamlllY Oechsli 'I'aylor, Commissioner Alaska Oil and Gas Conservation Comt11Ìssion January 2, 2003 PO BOX 100360 ANCHORAGE, ALASKA 99510-0360 Conoc6PhUlips Alaskå,lnc. ) ') Scott D Reynolds Hansen #lA Annular Disposal 1/2/2003 Andy Bond Robert Swenson CONFIDENTIAL - Hansen #1A Well Paul Mazzolini ATO-1570 ATO-1310 ATO-1368 Sundry.doc RECEI\/ED .I.AN 0 7 2003 i\!aska Oil & Gas Cons. Commiss!o 1.\ nchor;Jt.!E- Page 20f2 cc: File Reynolds Exploration Drilling Engincer 'Thc anticipated spud date for this well is 1::;'ebruary 15. 2003. If you havc any questions information, please contact Scott .Reynolds at (907) 265-6253 or Paul Mazzolini at (907) or requtre 263-4603 220 b b~§.....~""""'''~·· 1J.Øtfbbls ""'...../"....., To~.~J.:vóíume -!~..,,,,,. .-- .,;t"....~ further l6 __~ .........---....- ./ /" Comments...............· 'rhis volume is cucre.!).tJ~ the Water Base Mud (WB1vf) Volume of cqttHtg:(left in WBM Cell. V olU!Jl~-""'''óf water required to slurry 2850 bbls of ".......wâfêr/ slurry ratio. Solids from 4000' of 6-1/8" hole. Volume of water required to slurry 220 bbls of solids at ratio. Slurry Water Solids 52,145 bbls a 6:1 water: slurry Slurry Water Waste Stream Rain Water Solids 14,250 bbls Volume 33,725 bbls. 2850 bbls solids Cell at a 6:1 Estimated Disposal Volumes ) Ç.'.)~~~ d-I ') Scott D Reynolds Disposal fluid table update for AOGCCdoc 2-1 R-2002 6. 5 4 3 All of the cuttings operations. There are no plans to use the OBM cell for OBM cuttings and fluid storage during drilling operations in 2003. 6700 bbls of rainwater and pad run off water had to be moved from the WBM cell to the OBM cell to prevent the WBM cell from overflowing during the recent warm speno We are maintaining 2' of freeboard in the WBM cell. The pad has been re-graded to prevent more water from filling the WBM cell. The grading operations do comply with our storm water pennit. The new volumes shown above increase the total- as submitted with the Sundry- by 10,000 bbls; therefore, the volume increase requested increases to 140,000 bbls. ConocoPhillips plans on using some of the water in the OBM and WBM cells as make-up water for the mud, and slurry water for the grinding process. This beneficial re-use should lower the total amount of fluid disposed of in the annulus. Page 1 of 1 2 1 Other Comments were removed from the OBM cell during last summers grind and dispose Total V olwne Oil Based Mud Power Fluid Waste Stream Rain Water Rain Water Solids Slurry Water Solids Slurry Water 62,145 bbls 2600 bbls 700 bbls 220bbls 1100 bbls Volwne 33,725 bbls 6700 bbls. 2850 bbls 14,250 bbls Conunents This volume is currently in the Water Base Mud (WB1v1) Cell This volume is currently in the Water Base Mud (OB:M) Cell Volume of cuttings left in WBM Cell. Volume of water required to slurry 2850 bbls of solids water/ slurry ratio. Solids from 4000' of 6-1/8" hole. Volume of water required to slurry 220 bbls of solids at a 6:1 water/slurry ratio. Estimated volume of OBM used during the drilling operation. # 2 Diesel power fluid for the jet pump operation. This fluid is currently in the wellbore. Of the 1500 bbls in the well, 800 bbls will be saved and stored in on-site tank farm for end of well testing operations. at a 6:1 Estimated Disposal Volumes ) ) .r\ ~ ~ 0lV. ~ \Y\\ ~ V\:V 0' 8 9 7 6 3 4 5 Approval for PPCo's request to resume annular disposal 13-3/8" annulus of the Hansen #1 is recommended. PPCo's request to exceed the previously established 14.3 EMW the surface casing shoe of Hansen #1 is affirmed. (302-224) The disposal rate shall not exceed 2.5 bpm. The surface pressure while pumping may not exceed 1500 psi. (302-224) After resuming disposal at the higher-pressure conditions, PPCo shall run temperature logs to confirm where the waste is being placed and provide this log to the Commission. These logging runs should include a base pass preferably conducted prior to resuming disposal and follow up pass(es) after disposal is underway. The logs should be run as deep as practical to potentially identify the waste-receiving zone(s). PPCo shall monitor the surface pumping pressure at all times while disposal is occurring and cease disposal operations if the pressure information indicates that the waste is not being confined below the shoe. PPCo shall maintain a log of their disposal operations noting the volumes of waste disposed, the weight of the slurry pumped and representative surface pressures while pumping different fluids (ie clear water or slurry). The disposal volume is increased to 140,000 bbls. Except as modified the remaining conditions of approval 302-224 and 302-006 still apply. 2 mit at 1 While conducting annular disposa following requirements apply. nto the 9-5/8" x under this revised approval (303-004 ) the Annular Hansen #1 a ) Disposal Monitoring Requ 203-004 303-004 rements ) of 3 2/19/2003 2:26 PM Scott, I checked with Steve McMains our stat tech on this the best information you have for the surface location. that would be the latest survey. For the Hansen #1, you should submit a sundry transmitting the new as-built and the updated information for the BHL and any other apply. It would be appropriate to have a transmittal information to describe what happened. Also, Steve McMains also informs me this well. At a minimum that information should have been submitted 30 days that there is no 407 in our files for letter with As matter. locations" You should use the Hansen #1 understand that may it, To: cc: Subject: Re: Hansen Survey Results Scott D Reynolds/PPCO@Phillips 12/24/2002 12:27 PM Tom Maunder <tom_maunder@admin.state.ak.us> Scott D Reynolds Drilling Engineer, Exploration (907) 265-6253 OFFICE (907) 240-5660 CELL Scott.D. Reynolds@ConocoPhillips.com Best Regards, Please Note the new email address Below Since the placement of the BLM monument may not reflect the true Township and Range Section Corner. I would suggest that we all use the consistent ASP Zone 4 "X" & "Y" and the LaULong coordinates in any discussions we may have. Thanks for looking into the surface location issue. A 403 with the final As-built was submitted with the most current information on or around October 24th, 2001. I will use the latest as-built survey for the legal description of the surface location in the APD for the sidetrack. Tom- Subject: Re: Hansen Survey Results Datè: Thu, 26 Dee 200208:57:13 -0900 From: "Scott D Reynolds" <Scott.D.Reynolds@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "Paul Mazzolini" <PauI.Mazzolini@conocophillips.com>, "Robert F Swenson" <BOB.Swenson@conocophillips.com> Re: Hansen Survey Results ) 2 of 3 > Scott D Reynolds > Drilling Engineer, Exploration > (907) 265-6253 OFFICE > (907) 240-5660 CELL > Scott. D.Reynolds@ConocoPhillips.com (See attached file: tom_maunder.vcf) 2/19/2003 2:26 PM > > At this point we need some direction as to what we should use for the new > APD. If we adjust the surface location to match the BLM monument, do we > also need to adjust our BHL to reflect the difference between the CPAI > calculations and the BLM monument? > > Please Note the new email address Below > > The cause of the error as explained by the McLane Consulting Group "could > be attributed to the fact the BLM rectangular survey that monumented the > section corners in this pariticular area was performed in 1918 and the BLM > did not have the means to determine their precise geographical location in > the field. " > > Township and Range Based on McLane Consulting Group calculations using the > As-built Northing and Easting: (I > calculations.) > 2009 FSL; 1458 FEL > See 2 T4S, R15W don't how they arrived at their > Township and Range Based on ConocoPhillips Alaska, Inc. (CAPI) calculations > using the As-built Northing and Easting: (Agrees with Baker Hughes Inteq > Theoretical Section Lines) > 2209.09 FSL; 1544.86 FEL See 2 T4S, R15W > > Township and Range Based on BLM Monument using the As-built > Easting: > 2148' FSL; 1527' FEL See 2 T 4S. R15W > can't find the Sundry we submitted!!! > (as submitted in a Sundry) > > >From the As-built: > Grid N: 2144659.501 > Grid E: 168820.636 > Latitude: 59 51' 30.098" > Longitude: 151 48' 5.720" Northing and > In the process of developing the directional plan for the Hansen #1 A > Sidetrack, a discrepancy in the Township and Range lines between the ')!\s > Built" surface location and the "Theoretical" surface location has been > discovered. > Tom- > Scott you did submit Tom o Reynolds wrote: something on this Thanks after the testing was completed Re: Hansen Survey Results Would you check into this and let me know ) if ) of 1 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 12/24/2002 12:55 PM Pau., This is a follow-up to a note I earlier sent to Scott. Steve McMains, one of our stat techs, brought to my attention that we have not received the completion report for the subject well. I have checked the file and although I found a lot of information, I did not find a 407 or a 404 there. With ongoing activities, it is sometimes possible to lose track of the paperwork. Regulation 20 MC 25.070 addresses reporting requirements and the general requirement is "within 30 days" a report should be filed. We would appreciate if you would put submitting this paperwork on top of the New Years list. Please call either myself or Steve (793-1241) with any questions Tom Maunder, PE AOGCC Subject: Hansen #1 Date: Tue, 24 Dec 2002 12:49:47 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul Mazzolini <pmazzol@ppco.com> CC: Scott Reynolds <sreynoI2@ppco.com>, Steve McMains <steve_mcmains@admin.state.ak.us> lrIansen #1 ) ~o \ , ) ':.J ~ !:ìu'W;'M "" I 4, ~~s-SL ø,';.'~ .' \tI\\'~''''-·''~-/~ .-l ".. ' . \. - l.\kI\j"Lr- \fl) , A .. i(çUV\ (·;\~fÜS:L. ') \, (/\ ,. ~() SiM.D PÛ'\I o~'* ) ( QJ.aL~+v pe~ I ) iùlS) jÒ2- j¡õ-tL~) Regional Citizens Advisory Council * 910 Highland Avenue, Kenai. AK 99611-8033 Phone: (907) 283-7222 * Fax (907) 283-6102 Mllnicipality of Anchorage Kenai Peninsula Borough ... Cook Inlet What has become apparent during the series of meetings regarding this discharge is there is the strong potential that this discharge may not be stopped. What also has become clear is that there are no readily standard remedial procedures to stop a discharge from an annular disposal well in Cook Inlet. Hopefully the water flood project will be the solution to this ongoing discharge. If not, what other solutions are there to stop this discharge? Until there are viable solutions, CIRCAC recommends KodÚlk lslllnd Borough City of Homer During the meeting Unocal presented several proposals to stop. the discharge. They are currently developing a plan to inject seawater into the K-19 annulus at approximately the same pressure as the drill mud/cuttings injection rate. Unocal predicts that the water flood will enter into the same zone as the cuttings inj ection and force the diesel to the surface where response equipment will recover the discharge. This plan will be presented to the agencies in the near future. City of SeldovÚl City of Kenai City of KodÚlk The purpose of the meeting was to discuss an ongoing subsea oil. discharge in Cook Inlet. The discharge has been traced to a.well, K-19 on Unocal's King Salmon Platform. This well has been pennitted by AOGCC to dispose of oil based drilling mud and associated cuttings via annular injection. Currently the discharge appears at certain tidal and weather conditions in the form of spot sheening near the platform. Fishing OrganiZlltions A meeting was held on September 16, 2002 at the Alaska Department of Environmental Conservation (ADEC) Offic~ in Anchorage. In attendance were representatives from the United States Coast Guard (USCG), The· Cook Inlet Regional Citizens' Advisory Council (CIRCAC), ADEC, and the Alaska Oil and Gas Conservation Commission. Aquaculture Associations Recreational Groups Cook Inlet RCAC (C1RCAC) is an independent non-profit corporation whose mission is to represent the citizens of Cook Inlet in promoting environmentally safe marine transportation and oil facility operations in Cook Inlet. Our 13 member Board of Directors represents seven cities and boroughs within the region, along with commercial fishing groups, aquaculture associations, Native interests, recreation groups, state Chamber of Commerce, and environmental groups. Environmental Groups Dear Ms. Taylor: Alaska Native Groups Alaska State Chamber of Commerce Ms. Cammy Eochsli Taylor Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue # 100 Anchorage, AK 99501-3539 October 10, 2002 AtllkaOit 'GI&Cons.Commission A~~ Members .. OCT 1 5 7002 RECEIVED ~ t' i RCA.C .J ..J J//YL The mission of the· Council is to represent the citizens of Cook Inlet in promoting environmentally safe marine transportation and oil facility operations in Cook Inlet. " Cook Inlet Regional Citizens Advisory Council * 910 Highland Avenue, Kenai. AK 99611-8033 Phone: (907) 283-7222 · Fax (907) 283-6102 We would like the AOGCC representative to provide a list of the number of these types of wells in Cook Inlet noting any problems that have occurred in their operation. It would be appreciated if your representative would also be available to answer questions from the PROPS. Committee members during the meeting. Feel free·to give Mike Munger, Director of Operations a call at (907) 283-7222 to discuss this issue. I look forward to hearing from you or your staff. CIRCAC requests that a representative from AOGCC attend the next CIRCAC PROPS Committee meeting in Kenai on November 22, 2002. This committee deals with prevention, response, operations and safety issues in r~gards to crude oil marine transport and crude oil facilities Inlet. in Cook " " that the AOGCC review the operations of all Cook Inlet annular disposal wells and suspend future permitting of annular disposal operations in Cook.Inlet until such time as the AOGCC and the Cook Inlet oil operators have developed a plan to deal with subsea discharges of this nature. While CIRCAC supports the rationale of annular disposal, which reduces the potential for pollution by an accidental discharge during transportation of oil based mud and cuttings to another disposal facility, the ongoing pollution in this case is unacceptable. ~ J 'The mission of the Council is to represent the citizens of Cook Inlet in promoting environmentally safe marine transportation and oilfacility operations,in Cook Inlet." of2 0/15/2002 If at all possible we would like to get app;r..ewaa_~~ddi...{¡::i'0na'~oìume"!'~~±n"" orde;r_ I~ ·p~cess~l1røs1:det"!"ã~~~~· -·TeCtl-··'è":rm~" . We anticipate 3950' of 6-1/8" wellbore or i.~~-f......ø\i~ng·s~...Ï:1...-,~- ....ctu~e-ho~e. Since it'll be an invert job, I'd bump that by 20% to 175 bbls. We're planning an uncemented slotted liner so there's no excess volume associated with cement but we may do a liner wash so that would be another 175 bbls or so that we possibly would divert to the pit (though we may just ship it to tanks for ? storage). Of course, t..h.~w:L1..,1, h~. ,>,:"ç.';~-: T·!a-&P-r.""oR~TN ,u~~L-arã.\;::-WÏ'Il ~ prohi2.!JJx ~eø.a-m\iLeb., _ rp\.1~b,,"J.aT.,gew_vßd..t1mC Mt:cm:-~...LÜyL-4!"~"'1~~en~~d'" <A.~u.mp N'V vo~me~m-ehe-cei.~d.:t , ·....~ml-~rj'\.1L .t!~H.:. ~:re·ëiI.dn~, ~t..,--. - ~'1."a"'ItrTi~ kep.pj~g qí¡\i?-h ¿4~pen-b,\':4.> '::-I1cn..~é' l.u L.:'!\::: ~"~.uL. W'= Ilci.Ve s'U'~e·SS--ci.'tl't1-trè"C'1de ~~ to (j.y,..) 1 .3.- 2nd.. ::r~-d~'S'r'OúL--::r vve~l b.r L.ue- soutnerIl .L.d.d'i L H lrl.\::1~. for some guidance on what would be a reasonable request- for dMJ;~ Looking 1 7AM Tom, down at Hansen we anticipate finishing up our disposal operations tomorrow with a total disposed volume of right at 70,000 bbls. ~~ apBr"p~,wa'FJ.~tft'~"'75'v¡.o-O--oo;arg(Yll!a:~:L-eas~~I-'ØIi~.~'@'6~'P"""'Shbrt. . We have the sidetrack that we plan on commencing around 12/1/2002. We are planning to sidetrack out of the 7" liner in order not to jeopardize the integrity of our disposal annulus, among other considerations do ^ Thomas Yeah, I'm still here Probably will be for another 4 or 5 weeks. McKay left on Tuesday - presonnel unfamiliar with routing protocol in The Houston Norwegian consuldte "gifted" him with a much earlier approval of work permit/residency visas than normal Our stuff is in Oslo waiting on approval Subject: Hansen #1 Annular Disposal Volumes Date: Wed, 25 Sep 2002 13:49:35 -0800 From: "William B Lloyd" <wlloyd@ppco.com> To: Tom _ Maunder@admin.state.ak.us Jim, Enclosed is note from Bill Lloyd at PPCo regarding annular disposal operations at their Hansen well. This was a-big bore, extended reach well drilled offshore from an onshore location.· They used oil based mud and disposal is a concern. He poses 2 things here. The first, waste from the sidetrack is I think approvable. Volume is small and it is from the wellbore or a portion thereof. The second item will be a little more difficult. While we have approved waste from multiple wells before on the slope, it really has never been at such great volumes. Regardless of the drilling waste, there will be the accumulated melt and rain waters. According to Bill, Sharon Alsup-Drake is presently preparing the report on annular disposal. Tom ~~ ~l J &i ;¡ ~J ~ -f 3> Subject: [Fwd: Hansen #1 Annular Disposal Volumes] Date: Fri, 11 Oct 2002 11 :08: 19 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jim Regg <jim_regg@admin.state.ak.us> CC: Cammy Oechsli <Camrny_Oechsli@admin.state.ak~us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Mike Bill <mike _ bill@admin.state.ak.us> ~wd: ftnlsen #1 ..,:~ '~tl.",":" Annular Disposal Volumes] ) \ \ ~(» l- 15 7 20f2 TOl11 Maunder <ton1 n1aunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 0/15/2002 7AM Bill Lloyd Sr. Exploration Drilling Engineer Phillips Alaska, Inc 700 G Street ATO-1568 Anchorage AK 99510 907.265.6531 office 907.244.5616 cell) 907.265.1336 fax) Thanks addi tional volumes for further disposal from the sidetrack work. Ofr"'t'h~e··~ tqp"""",9,tri"mY;e:xhead,'~maybe:·;·' an· ·incre¡a se·',;.oÉ,·:,2,s.?OO O':"bb'Ì's,....·to'i,:J: 0 O'·,rO,O O.:,·bb,¡§:,-Z;,:;.",,\.,Ai.s.o.ï>~\,in ~~~~ft'~~r;ël~.'~Biõ~~'î"~'~~·~~¡~'··t'~~~·~~;:~·~'fð~·~~'l·~'~.ð,~~~,~,~t,~~~~¡v~,~~b'~~·:t~;~,::~~o~,')~;'~..".' I~g'ã"št"tlìnf'ìY';t1:îe'¡ "'í:ntërrnedfå té··otl" H'àns·ê~n'·'#·2·"'wâ:s''''êêmënted.·.and ,.,te..~t.~;p. ),.? ) # Annular Disposal Volumes] 10/11/2002 1 :25 PM 10f2 Looking for some guidance on what would be a reasonable request for additional volumes for further disposal from the sidetrack work. Off the If at all possible we would like to get approval for additional volume in order to process our sidetrack cuttings "real time". We anticipate 3950' of 6-1/8" wellbore or 144 bbls Of cuttings in a gauge hole. Since it'll be an invert job, I'd bump that by 20% to 175 bbls. We're planning an uncemented slotted liner so there's no excess volume associated with cement but we may do a liner wash so that would be another 175 bbls or so that we possibly would divert to the pit (though we may just ship it to tanks for storage). Of course, there will be rain water and snow melt that will probably be a much, much larger volume than anything we generate, any sump volumes from the cellar, end of job pit cleaning, etc. We're planning on keeping both pits open but inactive in the event we have success and decide to drill a 2nd grassroots well to the southern fault block. Tom, down at Hansen we anticipate finishing up our disposal operations tomorrow with a total disposed volume of right at 70,000 bbls. Our approval was for 75,000 so at least for this one we ended up short. We do have the sidetrack that we plan on commencing around 12/1/2002. We are planning to sidetrack out of the 7" liner in order not to jeopardize the integrity of our disposal annulus, among other considerations. Yeah, I'm still here! Probably will be for another 4 or 5 weeks. McKay left on Tuesday ~ presonnel unfamiliar with routing protocol in The Houston Norwegian consulate "gifted" him with a much earlier approval of work permit/residency visas than normal. Our stuff is in Oslo waiting on approval. Thomas, Subject: Hansen #1 Annular Disposal Volumes Date: Wed, 25 Sep 2002 13:49:35 ~0800 From: "William B Lloyd·' <wlloyd@ppco.com> To: T om_Maunder@admin.state.ak.us /' ~ o ¡- ~ ~ a ~ t!; ~ Jim, Enclosed is note from Bill Lloyd at PPCo regarding annular disposal operations at their Hansen well. This was a big bore, extended reach well drilled offshore from an onshore location. They used oil based mud and disposal is a concern. He poses 2 things here. The first, waste from the sidetrack is I think approvable. Volume is small and it is from the wellbore or a portion thereof. The second item will be a little more difficult. While we have approved waste from multiple wells before on the slope, it really has never been at such great volumes. Regardless of the drilling waste, there will be the acçumulated melt and rain waters. According to Bill, Sharon Alsup~Drake is presently preparing the report on annular disposal. Tom Subject: [Fwd: Hansen #1 Annular Disposal Volumes) Date: Fri, 11 Oct 2002 11 :08:19 ~0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jim Regg <jim_regg@admin.state.ak.us> CC: Cammy Oechsli <Cammy_Oechsli@admîn.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Mike Bill <mike_bill@admin.state.ak.us> [Fwd: Hansen #1 Annular Disposal Volumes) ) ) 20f2 10/11/2002 1 :25 PM Bill Lloyd Sr. Exploration Drilling Engineer Phillips Alaska, Inc 700 G Street ATO-1568 Anchorage AK 99510 907.265.6531 (office) 907.244.5616 (cell) 907.265.1336 (fax) Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder <tom maunder@admin.state.ak.us> Thanks top of my head maybe an increase of 25,000 bbls to 100,000 bbls? Also, in light of a 2nd well bore, what are your thoughts about a 3rd extension for Hansen #1 disposal down the road for disposal of Hansen #2 volumes (at least until the intermediate on Hansen #2 was cemented and tested)? [Fwd: Hansen #1 Annular Disposal Volumes] ) recommend approval of Conoco/PPCo's proposal f~~~ Tom Maunder, PE M:\tommaunder\Welllnfonnation\By Subject\Abandon-Suspension\021011-Hansen 302-319 \0/ l-<:J;) I believe as presently configured with pressure tested plugs, the well meets the criteria required by (i). The work PPCo proposes to do involves removing one of the tested plugging devices, but it will be replaced with another device that will be pressure tested prior to initiating sidetrack operations. I believe what PPCo has proposed will satisfy the regulatory requirements. Since the wellbore has no open hole, mechanical plugs are allowed by 25.112 (c) (1) (E). The section does have a requirement of a minimal amount of cement on top of the plugs, but 20 AAC 25.112 (i) gives the Commission discretion if the proposed plugging is at least as equally effective and will prevent fluid movement into sources of hydrocarbons or freshwater. When PPCo completed the well, the production tests were not very successful. They believe that an emulsion was created in the near wellbore area that has severely damaged the permeability. Although that may be possible, their pump in test seems to indicate very tight rock. The equivalent bottom..hole pressures based on their surface pressures are very high. 20 MC 25.112 (c) (1) (E) [plugging of perforations that are isolated from any open hole] and 20 AAC 25.112 (i) [discretion to approve a variance ..if... equally effective plugging]. The pertainent portions of the plugging regulations are: Conoco/PPCo is planning to plug back and sidetrack the subject well, The well is an extended reach (18630' md I 7418' tvd). C/PPCo proposes to abandon the well with a combination of the existing completion equipment (packer with plug) and a retainer for setting their whipstock. They do not propose to use cement due the '¡tightness" of the perforated zones and the limited distance between the 9-5/8" shoe and top perforation. Conoco/PPCo Hansen #1 201-157 302-319 ) NOTE TO FILE ) () t."J D t, \, , . Alaska Oi~ & Gas Cons. Gomm15SIOf¡ Anchorage OCT 0 g 2002 RECE I VED WUskad PAl Drilling f you have any questions Phillips Alaska, Inc. submits the attached Application P&A operations on the Hansen #1 well. regarding this matter, please contact me at 265-6531 for Sundry Approval for the Dear Subject: Commissioner: Application for Sundry Approva for Hansen #1 (201-157) Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 October 4.2002 ConocriP'hillips ) ) P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6531 wlloyd@ ppco.com William B. Lloyd Sr. Drilling Engineer Drilling & Wells Signed /. ~ Paul MaZZOlin// & /; ~ FOR COMMISSION USE ONLY Conditions of approval: No{ity Cò~ssion so represe~tive may witness ~50û ~\ ~"ð\>~~ ~~~\)VJ Plug integrity ~ ........, BOP Testþ Location clearance _ I or- .. \ \ M~anicallntegrity Test ~bsequent form required 10- \..\'0 "\ +"'~~\ '!;OV-\t.~~ ~~~\f)~ ~~,,~~~~ .1It.."'1 Ongmal Signed By Cammy Oechsli Taylor Form 10-403 Rev 06/1 5/88 SUBMIT IN TRIPLICATE Approved by order of the Commission Commissioner Date Approval n:3o 2.. - .3 19 ð '(6?- Date approved to the best of my knowledge. l.n¢~ ~ . Title: Exploration Drilling Team Leader Date Prepared by Sharon Allsup-Drake Name of approver 7. I hereby certify that the foregoing is 16. If commencing operation December 1 proposal was verbally approved 2002 Service _ Oil Gas_ Questions? Call Suspended _ Bill Lloyd 265-6531 I 4. Estimated date for Detailed operations program _ LOT test, surface cement details and casing detail 5. Status of well classification as: No SSSV Description summary of proposal _X Refer to attached morning drilling report for 111III016 Gas OonS. COmm\SSIon JItChO)'Rn8 BOP sketch _ sheets, schematic 13. Attachments Packers & SSSV type & measured depth) SAB packer @ 6525' SAB packer @ 17502' Tubing (size, grade, and measured depth 3.5". L-80 @ 5443' OCT 0 8 2002 RECEIVED true vertical Effective depth: measured true vertical Casing Length Structural 93' Conductor 698' Surface 5177' Intermediate 16825' Production 8630' Perforation depth: true vertical 7098' - 6958'. 6924' - 6742' measured 17915' Size 30" 20" 13.375" 9.625" 7" 7555' 7465' Driven 488 sx Class G lead & 315 sx Class G tail 386 sx 12.5 ppg Class G, 504 sx 15.8 PPQ Class G, 96 sx G Neat 116 sx Class G, 474 sx 15.8# Class G 172 sx LiteCrete 16965' Measured Depth 93' 696' 5175' 6823' 8622' 6693' 7418' 3340' 93' 696' At total depth 900' FNL, 2. Present well Total depth: 307' FEL, Sec. 33, T3S, R15W, SM condition summary measured 18630 7418 P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2148' FSL, 1527' FEL, Sec. At top of productive interval 1750' FNL, 1641' FWL, Sec. effective depth At 2, T4S, R15W, SM 33, T3S, R15W, SM (as proposed) (asp's: 155036, 2152496) feet Plugs (measured) feet feet Junk (measured) feet Cemented True vertical Depth Cosmopolitan Project 8. Well number Hansen #1 9. Permit number / approval number 201-157 10. API number 50-231-20010-00 11. Field / Pool Exploration PRN plug @ 16567' & 17544' Baker N-1 CIBP @ 16450' Development _ Exploratory _X Stratigraphic _ Service _ ConocoPhillips Alaska, Inc. 3. Address 1. Type of request: 2. Name of Operator Abandon _XX Alter casing _ Change approved program _ 7. \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operational shutdown _ Re-enter suspended well _ Plugging _ Time extension Stimulate _ Pull tubing _ Variance _ Perforate 5. Type of Well: 6. Datum elevation (OF or KB feet) Suspend _ Repair well _ ) 163' RKB feet Unit or Property name kr\OllI t^ ..O lo/llltr4 Other _ X-plug in 2/26/2002 PRN plug 3/9/2002 in Tyonek Completion Assembly tested to 3800 psi on (Prior to setting plug, pressure test against open perfs Existing Tubing Tail Plug Testing Details Hemlock completion assembly tested to 3750 psi on Tubing: 3-1/2" 8.5" Baker N-l C1BP set SLHT and 3-1/2" L-80 Landed @ 5443' MD @ 16450' MD and tested to 3500 psi Tyonek Perforations: 17465' - 16965' MD Baker 80-40 x 10' PBR w/scoop guide for 9.625" casing Baker 80-40 E-22 Anchor Tubing Seal Assembly (8rd) 9.625" Baker SB-3 Hydro-Set Production Packer with millout extension 3.5" WTS-6 Tubing as necessary for proper packer setting 8.5" OD x 3.5" WTS-6 Centralizer w/XO 2 jts 3.5" OD 9.6 ppf L-80 tubing (slotted) Halliburton 3.5" OD x 2.329" No-Go (2.329" PB) RN nipple profile 3.5" WTS-6 tubing 3.5" 8rd x 3.5" WTS-6 XO 3.5" OD 8rd ported sub 2.875" 8rd x 3.5" 8rd XO 2 - 3.375" OD x 2.875" 8rd extended time delays 3.375" OD x 2.875" 8rd time delay firing head Set RRN plug in RN nipple and tested to 3800 psi. and XO's single and Hemlock Perforations: 17915' - 17555' MD Baker 80-40 x 12' PBR w/scoop guide for 7" casing Baker 80-40 E-22 Anchor Tubing Seal Assembly (8rd) 7" Baker SAB Hydro-Set Production Packer with XO's; 17501' MD 4.5" Millout extension 2.875" x 4.5" XO 1 jt. 2.875" 8rd tubing Halliburton 2.875" OD x 2.313" No-Go (2.313" PB) XN nipple profile run w/2.205" No-Go 1D w/X plug in place and tested to 3750 psi. Pkr @ Existing Configuration 20" 106#/ft X-52 @ 696' MD/696' 1VD 13-3/8" 72#/ft L-80 SL-Boss @ 5175' MD/3340' 1VD 9-5/8" 47#/ft & 53.50#/ft L-80 SL-Boss @ 16823' MD/6693' 1VD 7" 26#/ft L-80 SL-HT Set @ 18622' MD/7418' 1VD (TOL @ 16627' MD/6634' 1VD Existing Casing Program Objective Permanently abandon the original 7" completion intervals In the Tyonek and Hemlock intervals. Prepare the well to be sidetracked below the 9- 5/8" shoe @ 16823' MD and top of the first Tyonek perforation @ 16965' MD in the existing 7" liner Hansen # 1 P&A ) Procedure \ as follows: Made several attempts to establish injection below 2050psi. 1st 2000 psi, bled to 1900 psi in 15 min. 2nd 2020 psi, bled to 1920 psi in 17 min. 3rd 2050 psi, bled to 2000 psi in 10 min. Break down formation initial 4000 psi 0.3 bpm, gradually broke down to 3-3.3 bpm 3500-3850 psi, 225 bbls total pumped in well. ISIP=3186 psi.) ) ) rate 12. POOH and LD bit. PU Baker CIBP on end of tubing and RIH. Set CIBP rv30' below the 9- 5/8" shoe @ 16823' MD to insure window will be below the shoe but above the top Tyonek perf. 13. Pressure test CIBP to 3500 psi for 30 mins 14. POOH with Tubing. Prepare for sidetrack RIH with 6-1/8" rotary bit and clean out to top of Tyonek perfs @ returns are as clean as possible prior to TOOH. SLMOOH. 9. 10 11 16965' MD PU packer mill/retrieving tool combo and tandem boot baskets and l1H Circulate to clean out debris and POOH with packer and tailpipe assembly. LD packer, tailpipe, and gun assembly. Insure M PU PBR retrieving tool, jars and 4-3/4" DC's on tubing and RIH. Engage K-anchor packer and pull same. POOH and LD PBR and K-anchor and retrieving tool packer. 8. 6. 7. n Invert mud Mill up CIBP and circulate to clean out debris to top of packer. Rotate at high RPM and RIH slowly to top of packer. TOOH and LD mill and baskets. Note recovery from baskets. 2. 3. 4. 5. Transport #4 diesel to location and mix ND Tree, NU BOP and Test same 3-1/2" tubing and LD same 2 tandem boot Displace diesel/crude mixture from wellbore with PU metal muncher mill, CIBP @ 16450' MD. baskets and RIH on 3-1/2" work stri ng l1H top RU and pu the 90/10 Check and record pressure on tubing and annulus topdrive system Invert emulsion OBM to spec In rig pits 1. Procedure ) Bleed off to pits as necessary. ') RU 9-5/8" 7" CASING ~ Hemlock Perfs: 17555' - 17915' Completion rev 2 ~ rr ..'.~:!.~. ,...'.~..................?I['..~%@..i..". ,.. .1~~~~_~.if ...?..... ,lffil!!l '\.;::: Jd Jan. 0,2002 LOWER COMPLETION ASSY. Baker 80-40 Polished Bore Receptacle Baker 7" 84 SAB 40X32 Permanent Packer Baker Mill-Out Extension wI 4-1/2" LTC Pin down w/XO 2-7/8" 6.5# L-80 EUE 8rd Tubing 2.31" Halliburton XN Nipple (plug installed) wI 2-7/8" EUE 8rd .._--~ .... .....,,"'*,','.w .r:-I OJ OJ Þ ~:!$='"'' ". ,~p:'n""" .---,.. 'n_, '·":,',¡'I.'·:~"'::¡ cl SJ II I III. I II ~ Tyonek Perfs:-·w"., 16965' 17915'"::·-,,,,~~; ~::= -...",- ~. ~ · · · · · 4-5/8" Spacer gun centralized tandem top Halliburton Millennium Gun wI Stirn gun Halliburton Extended Time Delay Halliburton Extended Time Delay Firing Head Ported Bull Plug 9-5/8" @ 1682 Top 7" Liner 16627' Halliburton Gun Assembly · Ported Sub · Halliburton time delay firing head firing head . Halliburton extended Baker ZXP Liner 7" X 9-5/8" 3-1/2" SLHT L-80 Tubing Flex Lock Liner Hanger (Slotted) 8-1/2" 9-5/8" Baker No-Go Centralizer wI 3-1/2" Hanger Packer 9-5/8" ~ PH6 Connections Baker 80-40 Polished Bore Receptacle wI PH6 Box up. Baker 9-5/8" SAB Permanent Packer with Mill-Out Extension wI 3-1/2" PH6 pin down 3-1/2" 12.95# L-80 Tubing wI PH6 Connections 2.56" Halliburton RN Nipple (plug installed) wI 3-1/2" PH6 3-1/2" 12.95# L-80 Tubing wI PH6 Connections 3-1/2" L-80 Tubing @ 5443' Baker Type N CIBP @ 16450' MD 3-1/2" Well HANt ) # 1 Existing Completion \, .,ø..'. I ~ Con'ocoPlhiillips 9-5/8.. Completion rev 2 7" CAS I NG Packer @ 17501' Hemlock Perfs: 17555' -17915' Top 7" Liner 16627' 9-5/8" CASING Tyonek Perfs: 16965' 17915' 9-5/8" shoe @ 16823' ~ ~ ·1·····~····.J····,y·········""··n IL~,,~.:~_:~ ...'C .w. --~ r Jan 10,2002 ~ LOWER COMPLETION ASSY Baker 80-40 Polished Bore Receptacle Baker 7" 84 SAB 40X32 Permanent Packer Baker Mill-Out Extension wI 4-1/2" LTC Pin down w/XO 2-7/8" 6.5# L-80 EUE 8rd Tubing 2.31" Halliburton XN Nipple (plug installed) wI 2-7/8" EUE 8rd Baker Type N CIBP @ -16850' MD We HAN~ ) # 1, Proposed Plugged and Abandoned \, .... .,,f'" I ~.. ConocoPhiIUps · · The injection contractor employees were given waste management training by PAl's Kenai-based Environmental Coordinator. This training emphasizes the differences between Class I and II fluids and the importance of segregating them. This is the same training required of Certified Waste Generators on the North Slope. The employee who made the allegation did not actually see lube oil being dumped into the slurry tank. His allegation was based on an oily sheen observed on the grating covering the opening to the slurry tank. The oil-based mud and the used lube oil are visually indistinguishable · During PAl's Investigation Currently at the Hansen #1 well site, oil-based mud used during the drilling of the Hansen #1 well is being removed from a lined on-site pit, slurried, and injected into the annulus of the well. This activity is authorized by the Alaska Oil and Gas Conservation Commission (AOGCC) Sundry Application #302-224. Periodic maintenance of the injection pump generates both Class II oil-based mud as well as Class I lube oil from the pump. During the pump maintenance~ both fluids are placed into buckets and the Class I lube oil is recycled back to the pump, while the Class II oil-based mud is put into the slurry tank. Our initial notice and subsequent investigation was prompted by an allegation by an employee of the injection contractor that lube oil from the injection pump was placed in the slurry tank for annulus injection. we determined the following This letter is a follow-up to a verbal notice to your office on September 5, 2002 regarding a possible misinjection of fluids at the Hansen #1 well in Anchor Point. Since this time, a formal investigation of the possible incident was conducted by Phillips Alaska, Inc. (PAl). Based on our investigation, PAl cannot conclude that a misinjection occurred. Dear: Hansen #1 Well Sundry Application #302-224 RE Ms. Camille Oechsli Taylor Commissioner Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave., Suite 100 Anchorage, AK 99501-3539 Alaska 01& Gas COns. Comn1íISmJ Anehøraae SEP 2 3 2002 R!(EIVED September 19. 2002 David W. Hanson HES Supervisor 907 -263-4 7 45 907-265-6216 (fax) dwhanso@ppco.com (e-mail) P. o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 PHILLIPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY c;( êØ-)5 7 Cr'" v. c:~ Grkv David W. Hanson Tom Maunder - AOGCC PAl appreciates your patience while we made every effort to fully investigate this matter. PAl is committed to the proper handling of injection fluids and the training of our contractors. If you have any questions regarding this submittal, please contact me at the above e-mail address or phone number. · · The buckets used for the two fluids have been painted and labeled to easily distinguish their fluid use and disposal. A formal fluid handling procedure has been written and conveyed to the injection contractor employees. This procedure is clearly posted next to the injection pump for easy referral. Finally, PAl will meet with the injection contractor by November 15, 2002 to discuss recommendations for additional training of their on-site supervisors and employees · To address identified deficiencies in the fluid handling procedures used on-site contractor has performed the following corrective actions: the Injection Our investigation further determined that while no one directly saw a mishandling of the two types of buckets and none of the employees remember such an incident, we cannot preclude the possibility that it could have happened. However, because the injection contractor employees are trained to specifically know the difference between the two types of fluid and the regulations governing their disposal, it is unlikely to have occurred. '., · · Camille Taylor September 19, Buckets used not labeled. The procedure describing 2002 the proper to catch and '~ temporarily store handling of the two the two types of fluids ) fluid streams was not posted from the pump were Page 2 of 1 8/15/2002 9:22 AM Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Tom Maunder <tom maunder~admin.state.ak.us> Mike, Thanks for bringing over the latest temperature logging information since the next round of annular disposal was initiated. In addition to the initial authorization to conduct annular disposal, the Commission has lately provided an approval to increase the surface injection pressure which would also increase the ECD at the 13..3/8" casing shoe at about 5177' md. In order to demonstrate containment of the waste, a requirement of that approval was that a new series of temperature logs be performed after disposing of 2000 - 3000 bbls of waste. Due to the unavailability of the logging unit, a subsequent approval was given to allow a slight delay in performing the temperature logs. PPCo has since accomplished the logs and you brout)ht them over this morning. Bob Crandall and I reviewed the log prints with you and agreed with PPCo's assessment that the waste was being accepted by formations deeper than the 13-3/8" shoe. In particular it appeared that 2 zones were accepting the bulk of the fluid with the shallowest at about 5300' md. It is our assessment that PPCo has complied with the surveillance requirements of the approval to increase the allowable injection pressure. By copy of this email, PPCo has approval to continue the disposal per the conditions of the approvals. Good luck with the operations. Please keep us informed of any difficulties encountered. Tom Maunder, PE AOGCC Subject: Hansen #1-20j-157-Annular Disposal Date: Thu, 15 Aug 2602 09:22:02 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Mike Winfree <mwinfree@ppco.com> CC: Bob Crandall <bob _ crandall@admin.state.ak.us> Hansen #1-200-157 -Annular Disposal ) ) NOTES/ coMMf:Nl'S: Q<J.'-\ \ l ~~l ~ 'iD0 ~Csl~ ~ cgS31. ~ ~ Ç)e: \Ú,-\ 0t'--\' \ \-\o~'i 0 \'- ~ ~ sO ~ ,-'.H~X\ - ~ '-P ~, '\'è<=yÙ€=S \ \0 c0ÄJoC-\-OS'-~~~~o.\ ~\~?Ð"'>CJ.- \, ~00 \-d 0 (L 0- \(y'ctJ~ û-- \ -\ð cD~ "-.J L k Û-. --S ~ ~ ~~~Y7~\ 0\ ~{(jJ'U ~'?\~ Cy~~~¿\'D~ \.-!'-\O~\\ ~~dS\- ~(( \tb~{b\~~ Jv~Q.C(Ö,~'-'\ ---~ ~ \Ð~ \<f'--.Qu ~-\-~~ .~ ;;1 . ~ ~. ~1V1w VE ~c- '6\ ~ uo~ Nt)cc..L ~ . _ \. -pIlONE NO. (907) 279-1433 i?~\S~Cp. FAX NO. (907) 276-7542 RE' ~ .~, \)-\'-7 ~ '- ~ ':Jt-<\c - - = o URGEN1' o FOR "REVIEW o PLEASE coMM'EN1' o PLEASE F£PL Y o PLEASE }ŒcYCLE TO: ~\ S\)\" 'I'Z Q \ coMP~: \ Ù \7yCu F fJ{ NUMBE~ '~c:... C'..... - So aaS ·'PHoNE. NUMßEî l'ACSl~lLE 'T1tANS~l'T'TAL SHEE'T Fllolk .-.-- <:::::\ \ <Ð ~ \-\.0.. \J \'èJ<t~--" DATE: . \>..~ S \. ùoa if ;:õTAL NO. 01' P ¡..G n.¡a.UDIN<3 a::J'lER, i- ~ YOUR REFERENCE NUMBE~ ) \ ALASKA OIL & GAS CONSERVA'l'ION COMMISSION H3 VJ. 7'l'fl AVE, SUI'l'E 100 AÑCflORAGE, AK99501-3539 dQ\- \s-ì 1" ~ ~? <:.0 <;""'~,,,\""'c'" c: \\~~"'~~ .-<t"v~'" ~CJ ¿ '" \" c:..~t>. s~ \. " -\ ~ 'ð,>~",\), \10\-.)",,-1£. .~H'-\.O' c.ö,,~~\-\,",~~~ w\-~\~,~~~\Ü~~ \o~ \\\S\\tŒÛ"- , s -\- \.Q "<r cL." 'P '"h <í:. '\ oJ \ \> ~~.ç \ ":> . ~-\- ù -.),0. I. ~o.. ~ \~ ~ ~ \: " "-\0 ~ C)'t ~ "'. ... . So \ K:Q ~ \\i. >.:I, ~~J Cj. ~ ~\O,->o...\ \J-.)O- ~ \Iê c...<í:.\ -.1& , ~ \' <..0 """ '> ~ s ~~ ol d ~c..~s. ú.c..'-{)~\<~ W \\-.QÙ\\-c,..c..~\O~. %\--.."-" ~*-, ~'> ~...~<~ ~~~'ì~\ì, ..\~ ~""'"\"Q.\« W4S ~ \,~ ~~M.Q (G~ T,",,~ "'-:IcA<t.'VC>~\D~S ~ -\-~ "*- '2X<,,.~C<;.Q \ '" ~ ~ W~ 0:\ ,;) Io~........ Q c; ()O \:ù \ \lO'D ~.,; ,\" \1t C!;>s.~C>.. \¡ \<í::.. o.S\e.<í:. ""-"- t'... ~ ~\-\- "- ~\""«)o:- '\ I<-. ~M..'-'.\ \a~. T"k \c.&t 'ì h,~- -.1C.\0b Mú,\ \~c...~ ~ \>\0~"'~ ö,cJ",~~ fu ~ -\-~ ~\C>..«[~ .~\ 0.\ SO\ ~":, . -n'(L '\ "'\';.0\ <:"\0~ ~'~ ~ S\-c~,> 'X ~i:a \,"': \~ ~ ()~\ "'-.. 9,\:~",-r-(JC c.D~J;) ~ wO-~'\ ~c\-\.",> t<ü\-;.Jfo....u">~ \. W~ ~":,~ ~,4- d~ \::,et\c""S W)\-c.."-" TCQ~. , '.. . \N \-\,..........\ "* \ \ ~,~ ~ \ t--..~~O" Q.. ~,\~\:i~, ~a ?~~ \~ 'I--\. S. C>..~ <i:..-.5lk,-& W'\'\ \-.. \~ ,',,-,,\',-û.\ ~,>~\c;.. ñ\o-w'~ ~ ú<tJ'ù,\\c:,~ \ <tXs.r'.~"- 'sr~o'\ -\-a \0<s:5~ \ '> ~c..c:,""t"\Q~~Q.Jn _ 1þ:):.1'Y'0. ~ (":. ct;) .-O:¡'-!) ) FROM : PI=II DRILLING I=ITO 1467 907 265 6858 200¡ )-09 12:24 #457 P.01/03 ()O\-\5~ To: TomMaunder..AOGCC 8-9-2002 From: Ray Springer - Phillips Alaska,. Inc. cc: Bin Lloyd - P AI Re: Annular Injection temperature survey Hansen #1 To~ pursuant to my phone request this a.In., Phillips Alaska, Inc. requests a variance to the conditions of approval for sundry application #302..224 approved 7-30...02. In that sundry order a temperature log must be 1"1 funned after ~ 500-2000 bbls of waste are injected. Due to non-available of a Schlumberser logging unit until Monday~ we request permission to increase the aOlount injected to ....2800 bbls to allow the injection tonight of cuttings slurry re8dy to be injected and allow the grinding and injecting process to continue uninterrupted through the weekend. All other terms of the sundry order to remain as ordered. For your information we have injected on 8-2-02 &. s.. 7-02 a total. of 1825 bbls. Annular injection records of these two injections are attached to this fax. Sincerely, ~~~ RECE\VED 399..5003 cell AUG 0 ~ 20U). 399..5009 cell fax Bill Lloyd Alaska Oil & Gas Cons. Commission Anchorage 265-6531 26S-1336 fax FROM : PRI DRILLING RTO 1467 ) 907 265 6858 2002. r~)09 12:24 :1*457 P.01/03 ;20\- tS~ To: Tom Maunder.. AOGCC 8-9-2002 From: Ray Springer - Phillips Alas~ Jnc. cc: Bill Lloyd - P AI Re~ Annular Injection temperatUfe survey Hansen #1 To~ pursuant to my phone request this a.m., Phillips Alask, Inc. requests a variance to the conditions of approval for sundry application #302...224 approved 7-30~02. In that sundry order a temperature log must be þet. formed. after 1500-2000 bbls of waste are injected. Due to non-available of a Schlumberser logging wlit until Monday~ we request permission to increase the amount injected to -2800 bbls to allow the injection tonight of cuttings slurry re8cJy to be injected and allow the grinding and injecting process to continue uninten'Upted through the weekend. All other terms of the sundry order to remain as ordered. For your information we have injected on 8-2-02 & 8..7-02 a total of 1825 bbls. Annular injection records of these two injections are attached to this fax. Sincerely, ~~f¢n~ RECEiVED 399..5003 cell AUG 0 ~ 20Ul. 399..5009 cell fax Bill Lloyd AlaskaOi' & Gas Cons. Commission Anchorage 265-6531 265-1336 fax ) tt) IS) " tt) f9 a.. I"- IJ) '\t # IJ) N N .... RIG #: 1 DISPOSING INTO ANNULUS OF WELL: I ~ , PUMP ~ OIUGCNM START. RAtE ro FL~DI. 11MIE END I1MI[ . (BPII) ! ~ ' F\.e~~"'",,- t 'Z. '.3S t z ~ 'ir; ~ IS) ~ re . K~ 1'- \'is I~~~ð l.~ ,/..(~l~ . ~ ~ ~ 0 ~ ~ ~ 1-5 L. ro IJ) ro )I ID IJ) ID N I"- IS) ~ \. I"- ID '\t .... o I- a CJ z .... ..J ..J .... a: Q .... !t tM!GHT DØÞOSAI. M'ÐMSOR: I: o a: LL VERSt, .\ -' ) page....L of ~ PAl .. DAILY ANNULAR DiSPOSAL RECORD ~UU3 I ~æ HANSEN'" I BARRELS DISPOSED Wat under ÐI1Iøer fluid tvoe1 ~ 1"2.../0 Z- 1800 TO .800 HAS feR MUD ONL.Y: aTAl1C DIIPD&\I. : Oper.øDn 1hIt WATERrar J DIESEL (or O'FHER. TOTAl. PRESSURE PADBURB. 1111I..... Flulllln¡ . 'rwaI RriW.uII ~In CUMULATWE . WElG1fI' ' FUNNB. (PSI) (PSi) Waà MillS Mull ¡ Annull1. PmtctIJ1g w..... co......) VOWME. (PPG) IMCD6I1Y COYr.œNTB ~bO 9~ð ' .Q R,1.G, Lß 2.0 . ~~t1,-< 4)A7t:RWR.e;€R.~E'". 'fOG . t-Z-SO DR.t.C . ~1-5 5 =fS ~ 5"{P$ï~~ ~~:J.k~ ct '2.. 0 9ðC DRLb : 330 : 330 ' ~,. ' ~ATt:R ¡'?Rf?1ER~ ~' 9~~ WAJ'SR DéSB. WASH WATER OmER I I GEL Q.GEL X.1ND BICARB .. ....~ " "\ MUD TOTAL VOLUMES FOR DAY: I AODlßVSS USED:' : N£GHTS DAYS -IYDISRJ8ALS~ PAJ DAILY ANNUL.., )ECT1OH RECORD -.------ -'..I l ..... .(;...I!~ ..,t. 'I-"~. . ." rot.l før rGd'lr ~ TfJOIlh:tm JI'rMous,- _ ..~;'4 r: MIw roW Iwtiud"'" '-' <-?z-S' (1'-Lf' l ~,l t- '" ;\. '-\ -:1 PH6 I-P?~ ~.:.' t -- ,.- SCOTT D. RE"tNOl ~~ - ----- ---.-.----- ...--. ----- -- --. ----- ---- -- ) ) ") M IS! "- N IS! a. ['- LD 'It : : : RfG II: I DISPOSING "\TO ANNtJLUS OF WëU.: I . PAI- DAILY ANNULAR DISPOSAL RECORD . J I Page i of-.:L NABORS 273 DATE: ; I r¡ f-¡/o~ 1S00TO 1800 HRS 'It N N M HANSEN .1 BARREl.S DISPOSED- fUat under Dtoøer fluid tvDe} FOR MUD ONLY: PIJI,UI'; ITA 'J1C ~ OIJGIN OF i START RAn ! fl'RESIUAE ¡ I rwIOS rIM!; iIID TTMI! . (SPIll)' (PSI) , ~ .R.~O~:9ib':a~ ~ tðO re u 0':01 rz.~5C¡. t.S : .t ÐlBPO!UL OfI.-.tII)1I'IMt WATER far DIEBEL for OTHER I P~BURE gMlf'IIKI FIll..... Freta RIll w.b ~In¡ CPBI) w.... tIIId . Mud Atlnllw. ~ng Wmr CClII'III1IIIñI} . lO6tJ D~L6 fO '.100 .: Ot.c.~ 5'60 TOTAl , CUMtlLA1IWE : VOLUME WBGHT : RJNNEl ~. . VISCOSITY COIIMEH1S _ WIJŒR 11Rc'--sER . C.~rT'I"CS ,~&.u.~ ~, (l.',^, ..~. .~.... ~w"Tt!'~ Ua6St!~cF t\ -;")11.00 I, ~ :''It '2- , ,'6() J ~R"<' !.30 00 LD 00 lD LD lD N ['- m ;\ ".f:'f.0,". .! ['- lD 'It M o I- cr L'J Z .... -1 -1 .... œ Q ~ 1~~!ALSUÆ1M5Ol~ MUD ~Tcålltcm . "."jf;;.:~ -- WAJëR a.sse. WASH WATEA 01HER TDfaI' far ~ ~.JiW)I .~ ~ nRf IbrWa Ani¥i- I ["100 '.,~~ IqOf~ :>- GEL -Q.GEL X-THD SLCARB PHe '..\ TOTAl. VOLUMES FOR DAY: 1 ADOmvES USED: NIGHTS " L DAYS ; , IMYÐilSPOSAl.S~ 1~~q ~~' 'I Ò ~",..!, 1: o œ LL .-- - VëRS~" 3 PAl DAI.. Y ANNUL. JECTrON RECORD SCOTI n, RE\'Not !-2Ø41 --------._--- . .. ---------- .. ..-- ----------- - - ... -_.. ..--- -- ----... \ In support of their application, PPCo performed a temperature survey while disposing about 1000 bbls of their pit fluids. After conducting a baseline survey, PPCo positioned their temperature tool below the 13-3/8" casing shoe and began pumping. In a short report prepared by the logging engineer, it is noted that cooling was noted while the fluid was being pumped indicating that fluid was being pumped past the temperature observation depth. When the pumping was completed, an "after pass" was accomplished from 5320' (-140' below the shoe) to 4950' (-230' above the shoe). PPCo limited their investigation depth due to concerns of how 'Ç');lt!!1e logging tool would re-enter the tubing string hung in the well. The tubin(~ is not equipped with a wireline re-entry guide so there is some risk associated with running much beyond the end of the tubing. In the investigated intervals, a smooth temperature gradient is indicated with the coolest temperatures noted deeper than 5300' . Based on the plotted temperatures it appears evident that the fluid pumped during this test was accepted by formations deeper than 5300'. The reason for PPCo's request is that when honoring the 14.3 limit, the potential disposal rate is limited to about 1.8 bpm with a surface pressure of about 1050 psi. PPCo is requesting approval to use surface pressures up to 1500 psi, which would increase the calculated EMW at the shoe to about 15.9 EMW. PPCo expects that an increase in rate will be achieved by allowing the shoe EMW to be raised. Authorization for annular disposal of drilling waste was approved via Sundry 302- 006 on March 11, 2002. In support of that approval, a document was prepared that analyzed the available formation integrity information. It was noted in that document, that when the well was initially drilled PPCo did not test the formations below the 13-3/8" casing shoe to leak off. They performed a formation integrity test (FIT) that tested the formations below to the shoe to 13.0 ppg EMW. While disposing of accumulated rain water and snow melt (with approval), a plot of the pumping pressure data showed that the formation accepted the fluids at 14.3 ppg EMW. The pressure plot was steady and did not show any pressure decline while pumping which could be interpreted to indicate that a "frac" was growing to shallower intervals. PPCo has submitted a sundry application requesting approval EMW at the surface casing shoe as specified in the sundry authorized annular disposal into the well to exceed the approval that rJZ~ ( r¡f~-J ~ [~~10î/ 1 )",. ~ .....:~~ ~,,:' 5 "d.(.P~/'b> CdlcJ~C íJ~rlr~.¡J'd/) 1~1 1he. Ic.~, r:41Q.. cJf.r"~¡'Á'¡~~ (ifd~ C4J:~wf \=-o~ 'f 0 0 c- \~0 \--(Ç-0 NOTE TO FILE ¡~Ic, ....J -i c, 5~ ~ $40 'tJ · r\CêoS~~c-- ftPG PPCo Hansen #1...201-157 302-224 :¡:: c..Cr1,"\_L:- ~ . Request for exception to 20 AAC 25.080 (e) (2) k t(}-14/l ~ Tom Maunder, PE Sr. Petroleum Engineer ~/:) ~ PPCo's request to exceed the previously established 14.3 EMW limit the surface casing shoe of Hansen #1 is granted. 2. The surface pressure while pumping may not exceed 1500 psi. 3. After initiating disposal at the higher-pressure conditions, PPCo shall run an additional temperature log to confirm where the waste is being placed and provide this log to the Commission. This logging run should be performed after disposing of 1500 - 2000 bbls of waste and should be run as deep as practical to potentially identify the waste-receiving zone. 4. PPCo shall monitor the surface pumping pressure at all times while disposal is occurring and cease disposal operations if the pressure information indicates that the waste is not being confined below the shoe. 5. The remaining conditions of approval 302-006 still apply. 1 Based on this analysis the following is recommended ) ) at Depth of 3-112" open ended tubing Depth of 13-3/8" casing shoe 13-3/8" Burst Rating: Depth of 9-5/8" casing shoe 9-5/8" Collapse Rating: 5380 psi 16826' MD. 6695 6620 psi 4$Ohsl,~ -::.. Ç-\_ ":- ~ d ( <:0 '£ \..-\ ~ ~~~\\-\~~ \ 5284 5177 MD MD,3343 TVD (TOC @ TVD 15332 . \ ~ S' ~~\ Current Operating and Equipment Ratings are as Follows injection The rate of disposal during this period was 1.8 bpm. Phillips hereby submits that the previously approved injection pressure of 14.3 ppg emw at the shoe is lower than would have been safely attained with a LOT and the subsequent rate of 1.8 bpm applicable to the 14.3 ppg equivalent at the shoe does not allow for sufficient rate. By virtue of this Sundry Notice, Phillips hereby requests approval to increase the disposal rate to 3.5 bpm, within the constraints of Phillips Alaska Inc Annular Disposal guidelines of 1500 psi ",SC)\:) - \(J S 0\ =- '-\sa ~~~ ~~~\ On July 11 a baseline temperature log was run from 5250' MD to 5200' (attached). Annular disposal commenced at 1050 psi WHIP and 1.8 bpm until 0800 hours on July 12 after a total of 1050 bbls were pumped. After pumping -160 bbls of fluid (annular volume to the shoe is 300 bbls) a temperature drop of 1.5°F was noted indicating preferential flow down the top of the 13-3/8" x 9-5/8" annulus. As can be demonstrated on the log, the fluid was effectively exiting below the depth of the logging instrument and shoe of the 13-3/8" casing, with no evidence of channeling behind the surface casing MD (w.l.m.) and continued On March 11, 2002, Phillips requested, and was granted, approval to commence annular disposal into the 13-3/8" x 9-5/8" annulus of the referenced well. In part, the approval for this disposal was based upon the formation integrity test data gathered after drilling immediately below the 13-3/8" shoe. The Sundry Notice as approved, allowed for a disposal pressure not to exceed 14.3 ppg equivalent mud weight at the 13-3/8" shoe (5177' MD. 3339' TVD) Hansen #1 Sundry Notice Request for Higher Rate for Annular Disposal RE Anchorage AK 99501 Alaska Oil and Gas Conservation Commission 7th A venue 333 West Suite 100 July Phillips Alaska Inc 700 G Street PObox 100360 99510 Anchorage AK 18.2002 ) ) ) ) CONDITIONS OF APPROVAL FOR SUNDRY APPLICATION #302-224 Hansen #1 PTD# 201-157 Annular Disposal 1 The surface pressure while pumping must not exceed 1500 psi. 2 The calculated EMW at the shoe must not exceed 16.0 ppg. 3 After initiating disposal at the higher-pressure conditions, Phillips Alaska, Inc. must run an additional temperature log to confirm where the waste is being placed and provide the log to the Commission. The logging run must be performed after disposing of 1500 - 2000 bbls of waste and should be run as deep as practical to identify the waste-receiving zone. Warmback passes are recommended. 4 Phillips Alaska, Inc. must monitor the surface pumping pressure and rate at all times while disposal is occurring, Phillips Alaska, Inc. must cease disposal operations if any information indicates that the waste may not be confined below the shoe and notify the Commission on the next business day. Indications of non-confinement may include, but are not limited to, a pressure decrease while pumping or a rate increase at constant or declining pressure. Form FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. 1L Plug integrity _ BOP Test _ Location clearance _. ~2.- Z2.T \.4'1c Mechanical Integrity Test -. "Subsequent form required 1 0- rt~\-o...\"\~\......) \W-~s. t>aScL \ ;::~~~~~~ CL'Í--cg:~ \S()~lna'S1gW~~\~~\"~ \a~ o..\Ç~\\SOO~\)\S t)-~ð'~~SG.\ Approved DY order of the Commission Cammy 0echI/ Taylor Commissioner Date 1 ~0ijt? '/-" 0-403 Rev 06/15/88 OR h t) N¡~l~ SUBMIT IN TRIPLICATE .~ /j 17-. - A -/~ Signed 1 ~ c..v-'óc.r'-" Paul Mazzo/in¡ ð1/¿ð /þ.:)o2- Date Prepared by Sharon Allsup-Drake Title: Exploration Drilling Team Leader Name of approver Date approved Service - 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call William Lloyd 265-6531 6. I 14. Estimated date for If proposal July was verbally approved commencing operation 17,2002 SAB packer No SSSV Description summary of proposal Refer to attached morning drilling Oil _x Detailed operations program _ Schematic _ Directional report for LOT test, surface cement details and casing detail sheets, schematic 5. Status of well classification as: Gas_ Suspended _XX 3. Attachments Alaska Oïl & Gas Cons. ~ommlsslml Anchorage Packers & SSSV type & measured depth) @ 16525', SAB Packer @ 7502' Tubing (size, grade, and measured depth 3.5". J-55, 8rd EUE @ 5284' JUL 1 ( " 2002 true vertical 6653' - 6822', 7098' 6958' RECE VED Perforation depth: Intermediate Production measured 5177' 6825' 8630' 6694' 13.375" 9.625" 7" 17194' 17915' Surface Conductor Casing Structural Length 93' 698' Size 30" 20" Cemented Driven 488 sx Class G lead, 315 sx Class G Tail 386 sx 12.5 ppg Class G, 504 sx 15.8 ppg Class G, 96 sx G Neat 116 sx Class G, 474 sx 15.8# CI. 72 sx LiteCrete 7555' 5177' 16826' 8630' 3339' 6695' 7418' Measured Depth 93' 698' True vertical Depth 93' 698' measured true vertical feet feet Effective depth: 307' FEl, Sec. 33, T3S, R15W. SM condition summary measured true vertical 18630 7418 feet feet Junk (measured) At total depth 900' FNL, 12. Present well Total depth: (asp's: Plugs (measured) 55036,2152496) PRN plug @ API number 50-231-20010-00 11. Field / Pool Exploration 6567'& 7544' Sec. At top of productive interval 1750' FNl, 1641' FWl, effective depth At (as proposed) 10. 3. P. 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2148' FSl, 1527' FEl, Sec. 2, T4S, R15W. SM 33, T3S, R15W. SM 9. Permit number / approval number 201-157 Cosmopolitan Project 8. Well number Hansen #1 Add ress O. Box Name of Operator Phillips Alaska, nc. Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic Service _ Variance _ Periorate _ 6. Datum elevation (OF or KB feet) 163' RKB feet Unit or Property name 7. 2. Type of request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _XX APPLICATION FOR SUNDRY APPROVALS Re-enter suspended well Time extension _ - Stimulate _ Other _ STATE OF ALASKA ') ALASKA Oil AND GAS CONSERVATION COMMISSION ') i ,,l kr"ì¡ /3ZJ /' j~ of2 Joseph Dalebout Completion Spec. Kenai, Alaska(See attached file: Hansen #1 las.zip) ~ ... "\ \. . L -\- ,,~~\ u "'-C>.. ~({ ~ ':> ""~ \ \ö ~Cè \ -\-\-Q VI .doc)(See attached file: Hansen s,~..Ü ~í \L ~ p+"- · \:> ~\L....... ........"\ UL ~ \...R '-' <r ú.. '8r.:I¡~ \'-\ iX....:>C!.. s;\-;.. ~ o....~'-a '" a.~ "-.:>~,,-.., \:-~ck ~~S~ ,,>\, T ~ '\\L~ \\,<'tr n.~;<. So\- \: '> (). ~~m"a..\) \1( (-\.~ï "e~J S$L~~>~~ ~ 0 T "cc~~o~~\ \S\ \\ ,-~"7èJ 'Nt <y:>\tQ"8 ð\-~ '\:"C)"\ '( " 7/15/20028:12 AM ~ ~ \ ""'"'-\ \o.~o\'\... \4. "\ c~........... ~ \ ","-c \m "-'- co.. \ ''i.. \M.O~' o...t"\t.n-\-. ~'-\ \oct ö..\>~\C~,\o....\-« \-ö 80 G s.\-ct \? ~\-G ·4~\- Bill sorry 776-8155. Thanks it took so long, any questions call me at . , ) ~ ?Kü~~\cJ \I\..O ~~~ \ --\-0 ',~,«-~ ö,\·Q...~c..«¿d ~~ Tom \à-\ W 'L<;.~b \'\<; ~CJ ~ .. \'Dt~\O~<> ~"f:'::>~ \ ,~,\-Ð \ \<ç, Here are the temperature logs from the base line and pdst-1000 bbl disposal 1\ __ \ ~\ . period. Looks pretty clear that the disposal is going below the shoe. ~",,<=::::(t v---- ~ f\ f\. 0 ~ 6 \\'Ç-\Ú Also included is the evaluation of the log according toJoe Dalebout CO ~ ùc.'~ ~ . \ \. _a. . (' _ . 1 . ( - w/Schlumberger \'C)~'C..C) \v--..\~ ~~~~ \0 'J <:;J¿-\ t \-\o,:>-\- O-Ç-W,,\ ro ~ S'L~CQ\-\û '- ~Œ> \X'-~~ Q. ~ ~ Gt- \ S () \ b<L~ -....::,.~ ~ 'S \c:k') \~ C!X)\\~~~. .' ':~~ ~~ S-\-c:.Gl.è3:f ~r-\-"" 0.. ~(t r"-Cfù \ \:NJ Ð~ S<L,",0~i) ~~~ ~~ ~-\-" os+~ ~F \ 't>CD œið c0 '" :r: + \..... \~ ~ ~ -\- '\ '7CL ...),\¿j<t\"",.\-. ..-\ \x,\ ~r .\"-.ç 2~ "tt ~'DY"'~ ~~ " ~ ---- ~Oi\\~d roO ~'o \\ ' Ç>...:> '4'-'\..~~cJ ~ \,~ '-ö t' ~ \ , To: William B Lloyd/PPCO@Phillips cc: Subject: 07/121200205:38 PM Hansen #1 Temp. Log \~~ ~ E\J\w dalebout1@kenai.oilfield.slb.com (Dalebout, Joe (Wireline) ) Bitl Lloyd Sr. Exploration Drilling Engineer Phillips Alaska, Inc 700 G StreetATO-1568 Anchorage AK 99510 907.265.6531 (office) 907.244.5616 (cell) 907.265.1336 (fax) Forwarded by William B Lloyd/PPCO on 07/14/2002 02:30 PM Also, when we met in the atrium the other day, you mentioned the possibility of a sundry notice. Let me know if it's required and we'll get it put together and over to you. Thanks, Tom I'll be available on my cell (244-5616) tomorrow (Monday) and if I don't hear from you, I'll call you. We've removed virtually 011 of the cuttings from the water-based pit and are testing them for beneficial re-use. OUf plan is to move the dredge over to the invert pit and begin G&I operation on Monday. The rate we are currently constrained to according to the last Sundry, is a 14.3 ppg equivalent that effectively holds us to 1.5 - 2.0 bpm. This rate is way below our optimum processing rate so a higher rate would be greatly advantageous. Hansen #1 Subject: Date: From: To: Temp. Log Hansen #1 Temp. Log Sun, 14 Jul2002 14:37:43 -0800 "William B Lloyd" <wlloyd@ppco.com> T om_Maunder@admin.state.ak.us ) Hansen #1 Temp. Log ) . Name: Hansen #1.doc œJHansen #1.doc Type: WINWORD File (application/msword) Encoding: base64 Name: Hansen las.zip ~Hansen las.zip Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 2of2 7/15/20028:12 AM Joseph Dalebout Completion Specialist Kenai, Alaska The first pass (log_004) was made before any Injection had began to create a baseline pass to Show normal temperature above and below 13 3/8" casing shoe. Next the tool was placed below the 133/8" shoe at 5200' before the Injection was started. Once the injection was started the Temperature was measured for the entire injection period. This was to see if the cooling affect was identified below the shoe ( it was). After injection a log pass was made from 5320' to 4950' to see if there was a large temperature change above and below the casing shoe. Bill, SUBJECT: Hansen #1 TO: Bill Lloyd FROM: Joseph Dalebout Temperature log '- \$", DATE: July 12, 2002 ) dO , \:L \\-ù... \--~ " ) \ \ SC_lllblPIIP .....Ga&Qø.eu....js&Øt ArdØi(1, APR 1 6 RECE'VED ~(iZI CC: Robert Swenson, PAI Geologist Receipt: ~'.í"; (~o fJl'~) Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Prepared by: Sandra D. Lemke Phillips Alaska IT Technical Databases Date: State ot Alaska designated release date (AOGCC) Approx. 04/27/2004 Please check off each item as received, below. All The other copy is for your files. data to be held confidential until sign and return one of the two copies of the transmittal enclosed to address Plot Image Files, MetaViewer install) CD ROM DATA il Baker Hughes RWD- Gamma Ray/Propagation Resistivity/Neutron-Porosity/Density¡ Job 194636¡ image plots in both (.pdt and logged 01/06/2002, Inteq Meta Image Viewer-includes LDWG format-US llF and Hansen 1 502312001000 RE:Hansen 1 AOGCC Permit: DATE: 04/16/02 Hand delivered 201-157 Transmitted herewith is the Jollowinq: Lisa Weepie Alaska - Oil and Gas Conservation Commission 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 TO: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 FROM: ') Transmitted herewith is the followinq: Hansen 1 502312001000 Films ~mberger Modular Dynamic Formation Tester (MDT), run date Jan 6, 2002; UltraSonic Casing and Cement Imager, run date Jan 15, 2002 Please check off each item as received, sign and return one of the two copies of the transmittal enclosed to address below. The other copy is for your files. All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 04/27/2004 CC: Robert Swenson, P, Geol~ '- ... Receipt: . ~.t . ~_ Date: Return receipt to: Phillips Alaska; Inc. AlTN: S. Lemke, ATO-1486 700 G. Street Prepared by: Sandra D. Lemke Anchorage, AK 99501 Phillips Alaska IT Technical Databases RECEIVED JUN 1 0 2002 AJuka Oil & Gas Cons. Cormillion AnctKnge RE: Hansen 1 AOGCC Permit: DATE: 06/10/02 Hand delivered 201-157 Lisa Weepie Alaska - Oil and Gas Conservation Commission 333 W. ih Ave. Suite 100 Anchorage, Alaska 99501-3539 TO: Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 FROM: TRANSMITTAL CONFIDENTIAL DATA PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY ) ) PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TRANSMITTAL CONFIDENTIAL DATA FROM Sandra D. Lemke, AT01486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Lisa Weepie Alaska - Oil and Gas Conservation Commission 333 W. ¡th Ave. Suite 100 Anchorage, Alaska 99501-3539 RE: Hansen 1 AOGCC Permit: 201-157 DATE: 03/27/02 Hand delivered Transmitted herewith is the followina: Hansen 1 502312001000 CD ROM data V' Epoch CD ROM of well data /schlumberger- Processed CMR (LDWG format); contains processed CMR and Displays Job 22013 V Schlumberger-Open Hole edits; Job 22014 logged 1/5/2002 16846-18516'md 3.5" D ïsk /saker Hughes directional survey data; report and MD/INC/ AI. Color mudlog presentations V Formation logs in MD and TVD, drilling dynamics, MWD Combo logs, 2"=100' Color or Blueline Log prints V Combinable Magnetic Resonance Imager (color print) logged 1/6/2002 ~ CMR DMRP Processing - Job 22013; processed 1/14/2002 Sepia Paper reproducible Äpoch-Formation Log MD 2"= 100' *note: Baker Hughes MWD digital Logging digital data and display images to follow shortly If questions, please contact Cathy Worley (907) 265-1129 Please check off each item as received, sign and return one of the two copies of the transmittal enclosed to address below. The other copy is for your files. All data to be held confidential until State of Alaska designated release date (AOGCC) Approx. 12/2003 CC: Robert Swel ¡Iogist RECEIVED Receipt: {: ~ Date: r Return receipt to Phillips Alaska, Inc. f'''!~' p 2 7 '! 002 ,(\1 \ L ATTN: S. Lemke, ATO-1486 Prepared tAAlBaQi"~¡¡&ommission 700 G. Street Anchorage, AK 99501 Phillips Alaska IT Te~tabases Sincerely, R~,cJ, RayfSpringer Tom, as per our telephone conversation this a.m., , personally witnessed the rut'ining, setting of a 9-5/8" Baker model N-1 bridge plug @ 16450' m.d., and the testing of same to 350U'psí for 30 minutes. Weare presently in the process of laying down 3-1/2" drillpipe followed be the running of a 3-1/2'1 tubing kill string to 5284' m.d.. The well will be left with a back pressure valve installed. I understand Bill Lloyd is in the process of submitting a final sundry application for the temporary abandonment. Attached to this letter is a copy of the pressure test chart. Re: From: Ray.Springer Phmips Alaska me Bridge Plug setting Hansen #1 Tom Maunder AOGCC To: & Gas Cons. CommiSSiOn Anchorage 15 March. 2002 Alaska Oil MAR 1 5 2002 RECE VED JO \ \S~ ,. 2/ }, 1. 5/20 4 SAT 02:45 FAX 1 \ , " ~ir [fl,1 1 AJa,ska Oil ¡ Gas G'üns. Gomffi\SSlDt AnchoraOf RECEIVED MAR 1 5 2002 Ru)¿ ( Co ct,? D { B ì-'.à~~ pl~~ -5<4: ~ () f 'lD p~; 30M ¡¡J.. LoSS PUMP RA TE2 j S;M J Spoch Wells;te Sen'k:es, Inc. I I Page ~ of 1 \ RE¡MRKS ¡ I Printed 5:27 - Mar 15, 2002 í HOOK LOAD ! PUMP RATE1 r . - ( KLBS ~ SPM 5O~O I I i ! I ....., ~"~ ~ ~ :\I o h < t/.) ~ ..... =:> C\I "- ~ ~ ~ Jt~ II( ¡ ~ 04:10 ~ - t:==:: ¡ ! -{)4:2Q I( œ= J: === .! 04:30 =- 1:= £L. === 04:40 pt~~ ... If) - 04:50 I T'"= ...= ~ 05:00 05:10 I PILL PIT RlGWÁTCH2000 ..OR/LUNG RECORDER: I . I Wen N~: Hanse~ #1 ¡ PUMP PRESS! TOTL'PITV ! ~ ! BBLS r'a! ~ I Customer: Phill¡ JS TIME .c::...../ ! ~ /(1&-...... -, ~f " v ¡ '-' c-- ,que; -t r-:? . [ '1SR/d c, <':... ..; -;r£s ¡- DEPTH ft hh:mm N .) ') ) íf;)?:f 4-- ~Z 0%6 <I<S'- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _X Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 21481 FSL, 15271 FEL, Sec.2,T4S, R15VV,SM At top of productive interval 1750' FNL, 1641' FVVL, Sec. 33, T3S, R15VV, SM At effective depth At total depth 9001 FNL, 301' FEL, Sec. 33, T3S, R15VV, SM 12. Present well condition summary Total depth: measured true vertical 18630 7418 Effective depth: measured true vertical Length Size 931 30" 6981 20" 5171' 13.375" 16825' 9.625" 186301 7" Casing Structural Conductor Surface Intermediate Production Perforation depth: Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service (as proposed) (asp's: 155036, 2152496) feet Plugs (measured) feet Junk (measured) feet feet Cemented Driven 488 sx Class G lead, 315 sx Class G Tail 386 sx 12.5 ppg Class G, 504 sx 15.8 pp~ Class G, 96 sx G Neat 116sxClassG,474sx15.8#CI.I 172 sx LiteCrete measured 16694' - 17194',17915' - 17555' true vertical 6653' - 6822', 7098' - 6958' Tubing (size, grade, and measured depth 3.5", J-55, 8rd EUE @ 5284' Packers & SSSV (type & measured depth) SAB packer @ 16525', SAB Packer @ 17502' No SSSV Description summary of proposal _X Detailed operations program _ Schematic X Directional I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _ 14. Estimated date for commencing operation 15. Status of well classification as: March 16, 2002 16. If proposal was verbally approved -rø I"'t All lit u AI Pé IL M AfC,(,t-f '"2.. 2IJO z.. Name of approver Date approved Service 17. I hereby certify th.at the forego' e and correct tO~he best of m knowledge. Signed ~ (tJ1? Ti;le,' Exploration Drilling Team Leader Paul Mazzolim "- FOR COMMISSION USE ONLY Conditions of approval: Notify Com...n]ssion so representative may witness ~ 'Nez. \ \ ~w ~S~ Plug integrity Ä BOP Test _ Location clearance - Mechanical Integrity Test _ Subsequent form required 10- u.. CJ \. ~\~ (,).~~t'C~ö..\ Q:...i-~\~S ~/~\ -ÇJ~ ()..~"d ~I 'D~ ~~~~~. Original Signed By Comlny Oec:hsll DLJ~JL j l~J\TE, 13. Attachments Approved by order of the Commission Form 10-403 Rev 06/15/88 · Oil Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) 163' RKB feet 7. Unit or Property name Other Cosmopolitan Project 8. Well number Hansen #1 9. Permit number I approval number 201-157 10. API number 50-231-20010-00 11. Field / Pool Exploration PRN plug @ 16567' & 17544' Measured Depth 93' 698' 5171' 16825' 18630' True vertical Depth 93' 698' 3343' 66951 7418' R,ECEI\fED M/-U' J 4, 2· nO') i . ~ .U I., Alaska Oil & Gas Cons. Commission Anchorage _X Gas Suspended _ Questions? Call William Lloyd 265-6531 Date 3t1 ~ !o 7- Prepared by Sharon Allsup-Drake I Approval no. ~~ - Oq 'J Commissioner Date SUBMIT IN TRIPLICATE ) ) Phillips Alaska Inc March 13,2002 Extended Well Suspension Program Hansen #1 Current Profile: Well has two packers; one above the Hemlock @ 17502' and one above the Tyonek @ 16525'. Both zones have been isolated with a PRN plug in a nipple profile below each packer and both plugs have been tested to -3700 psi. See attached schematic. Perforated Intervals: Hemlock Zone: 17915' - 17555' MD (7098' - 6958' TVD) 6 spf @ 60° phasing Tyonek Zone: 17194' - 16694' MD (6822' - 6653' TVD) 6 spf @ 60° phasing Well is currently SI with tree installed and tested. Tubing and 9-5/8" x 3-1/2" annulus has -7.3 ppg fluid (combination diesel and crude used for jet pump power fluid). Due to tight/damaged reservoir, the well is unable to flow. Calculated GaR from Hemlock and Starichkoff zones is -160 SCF/STB OBJECTIVE: Phillips Alaska Inc desires to temporarily suspend this well for up to 24 months to evaluate well data collected during the test, and to evaluate further completion/testing potential. At this time it appears reasonable to believe Phillips may, within that time period, re-enter the wellbore as a sidetrack candidate. With that in mind, the temporary well suspension program is as follows: 1) Set BPV. NO Tree and NU BOPE. Pull BPV and test BOPE to 3500 psi. 2) RU Weatherford and pull 3-1/2" PH-6 tubing and accessories from PBR above 9-5/8" packer @ 16525' MD. LD tubing and accessories via laydown machine. 3) PU 9-5/8" CIBP on 3-1/2" HT-38 drill pipe and RIH. Set CIBP @ - 16450' MD and test same to 3500 psi for 30 minutes 4) LD -17500' of 3-1/2" HT-38 drill pipe currently stood back in derrick. 5) PU 5284' of 3-1/2" 8rd EUE kill string and RIH. 6) Set BPV, NO BOPE and NU and test tree 7) Install tree cap and remove all handles from tree and secure same. 8) RDMO Nabors 273. ) ) HANSEN #1 CURRENT CONFIGURATION ~  ZZ \J ~ - 1 joint slotted liner t6S69 - 96 6, IIIIII ~ .... 1 joint 3-1/2" slotted liner 16833 - 63 IIIII '~' o~ ~ Z :g ~ ~ ~ 20" Conductor Casing Set @ 698' ... 13-3/8" 72# l-80 Sl Boss Set @ 5177' MD/3341, TVD 9-5/8" SAB Packer Set @ 16525' MD/6601' TVD Tested to 3800 psi PRN Plug set in RN nipple @ 16567' MD/6642' TVD Pressure Tested to 3750 psi 1/30 min ~ 9-5/8" l-80 Sl Boss 47# to 16825' MD - 10034'/6695' - 4742' TVD 53.50# to surface Tyonek Perf Interval: 16694' - 17194' MD 6653' - 6822' TVD 6 - 0.38" dia jsp1 @ 60 degree phase 7" Baker SAB Packer Set @ 17502' MD/6938' TVD Tested to 3800 psi PRN Plug set in RN nipple @ 17544' MD/6954'; tested to 4000 psi 1/10 mins 7" 26# l -80 SlHT Set @ 18625' MDf7417' TVD TOl @ 16629' MD/6632' TVD ) ) Hansen #1 slot # 1 RT -Seabed= 175.00m RT-MSL= 175.00m MD DEVI AZIMUTH TVDBRT TVDS X Y NS EW DLS VSEC m deg deg m m m m m m deg/1 OOm m 0 0 0 0 -175 168820.7 2144660 0 0 0 0 495 0 0 495 320 168820.7 2144660 0 0 0 0 741 1.6 32.3 740.97 565.97 168822.6 2144662 2.9 1.84 0.65 -0.28 835 1.8 348.4 834.93 659.93 168823.1 2144665 5.46 2.24 1.37 0.54 927 2 260.4 926.9 751.9 168821.3 2144666 6.61 0.37 2.87 2.73 1025 4.8 256.8 1024.71 849.71 168815.6 2144665 5.38 -5.31 2.86 7.2 1118 7.5 272.7 1117.18 942.18 168805.7 2144665 4.78 -15.17 3.41 15.66 1211 10 286.3 1209. 1 1034.1 168792 2144668 7.33 -28.98 3.47 29.09 1307 12.8 292.3 1303.2 1128.2 168774.3 2144674 13.71 -46.83 3.16 47.86 1401 15.5 293.9 1394.34 1219.34 168753.4 2144684 22.75 -67.95 2.9 70.77 1495 17.8 296 1484.39 1309.39 168729.3 2144696 34.14 -92.35 2.53 97.67 1589 20.4 298 1573.21 1398.21 168702.3 2144711 48.13 -119.73 2.85 128.42 1684 22.7 298 1661.56 1486.56 168672 2144728 64.51 -150.54 2.42 163.31 1775 25 300.3 1744.79 1569.79 168640.4 2144747 82.46 -182.65 2.73 200.08 1866 27.7 300.8 1826.33 1651.33 168606.2 2144768 103 -217.43 2.98 240.41 1959 30.1 301.2 1907.74 1732.74 168568.3 2144793 126.15 -255.95 2.59 285.27 2052 32.8 300.7 1987.07 1812.07 168527.4 2144819 151.09 -297.56 2.92 333.7 2144 35.2 300.7 2063.33 1888.33 168483.9 2144846 177.36 -341 .79 2.61 385.07 2239 38.4 299.9 2139.39 1964.39 168435.5 2144876 206.05 -390.93 3.41 441.9 2333 41.2 300.6 2211.61 2036.61 168384.4 2144908 236.37 -442.89 3.02 502 2426 43.2 300.9 2280.5 2105.5 168331.6 2144941 268.31 -496.58 2.16 564.37 2519 45.5 300.8 2347 2172 168276.7 2144976 301.65 -552.38 2.47 629.27 2610 48.3 299 2409.17 2234.17 168220 2145011 334.74 -609.99 3.4 695.64 2704 51.6 297 2469.65 2294.65 168157.4 2145046 368.49 -673.52 3.87 767.58 2798 53.4 297.6 2526.87 2351.87 168092.1 2145082 402.69 -739.78 1.98 842.15 2894 55.2 297.6 2582.89 2407.89 168024 2145120 438.81 -808.87 1.87 920.11 2988 57.7 296.4 2634.84 2459.84 167955.2 2145157 474.36 -878.67 2.86 998.44 3084 59.5 296.6 2684.85 2509.85 167882.9 2145196 510.92 -952 1.88 1080.36 3178 61.5 297.1 2731.14 2556.14 167810.9 2145235 547.88 -1024.98 2.18 1162.16 3270 64.2 296.4 2773.12 2598.12 167738.8 2145274 584.71 -1098.08 3.01 1244.01 3362 67.4 297.3 2810.82 2635.82 167665 2145314 622.62 -1172.93 3.59 1327.91 3456 70.2 298 2844.81 2669.81 167588.6 2145356 663.29 -1250.55 3.06 1415.54 3551 72.9 297.9 2874.88 2699.88 167510.1 2145401 705.52 -1330.15 2.84 1505.64 3660 73.4 298.3 2906.47 2731.47 167419.5 2145452 754.66 -1422.18 0.58 1609.96 3754 73.4 297.9 2933.33 2758.33 167341.2 2145497 797.09 -1501.64 0.41 1700.03 3848 73.4 297.7 2960.18 2785.18 167262.7 2145541 839.1 -1581.32 0.2 1790.12 3944 73.4 297.3 2987.61 2812.61 167182.2 2145586 881.58 -1662.93 0.4 1882.11 4036 73.2 297.4 3014.04 2839.04 167105.1 2145628 922.06 -1741.2 0.24 1970.23 4130 73.2 297.7 3041.21 2866.21 167026.4 2145672 963.69 -1820.98 0.31 2060.22 4225 73.4 297.6 3068.51 2893.51 166947 2145717 1005.91 -1901.58 0.23 2151.21 4319 73.5 297.4 3095.29 2920.29 166868.2 2145760 1047.52 -1981.51 0.23 2241.32 4412 73.3 297.9 3121.86 2946.86 166790.4 2145804 1088.88 -2060.45 0.56 2330.44 4508 73.5 297.9 3149.28 2974.28 166710.3 2145849 1131.93 -2141.76 0.21 2422.44 4603 73.4 298.1 3176.35 3001.35 166631 . 1 2145894 1174.68 -2222.16 0.23 2513.5 4697 73.4 298 3203.2 3028.2 166552.8 2145938 1217.04 -2301.66 0.1 2603.58 4791 73.4 297.9 3230.05 3055.05 166474.4 2145983 1259.26 -2381.24 0.1 2693.66 4885 73.5 296.9 3256.83 3081.83 166395.5 2146026 1300.73 -2461.24 1.03 2783.77 4980 73.5 296.4 3283.81 3108.81 166315.3 2146069 1341.58 -2542.65 0.5 2874.84 5073 73.3 296.5 3310.38 3135.38 166236.6 2146111 1381.28 -2622.44 0.24 2963.95 5151 74 297.2 3332.34 3157.34 166170.7 2146147 1415.09 -2689.22 1.24 3038.79 5275 73.2 298.9 3367.35 3192.35 166067.3 2146206 1471.02 -2794.2 1.46 3157.73 5370 73.2 298.7 3394.81 3219.81 165988.8 2146252 1514.83 -2873.89 0.2 3248.66 5464 73.3 298.5 3421.9 3246.9 165911 2146297 1557.92 -2952.92 0.23 3338.65 5558 73.2 298.3 3448.99 3273.99 165833 2146342 1600.73 -3032.1 0.23 3428.65 5652 73.2 298.1 3476.16 3301 . 16 165754.9 2146386 1643.25 -3111.41 0.2 3518.64 5745 73.2 297.8 3503.04 3328.04 165677.4 2146430 1684.98 -3190.05 0.31 3607.67 5839 73.3 297.9 3530.13 3355.13 165598.9 2146474 1727.03 -3269.64 0.15 3697.68 5932 73.4 297.6 3556.78 3381.78 165521.2 2146518 1768.52 -3348.49 0.33 3786.78 6025 73.6 297.4 3583.19 3408.19 165443.3 2146561 1809.69 -3427.58 0.3 3875.95 6117 73.3 296.9 3609.4 3434.4 165365.9 2146604 1849.93 -3506.06 0.61 3964.13 6210 73.2 297.1 3636.2 3461.2 165287.7 2146646 1890.36 -3585.4 0.23 4053.18 6305 73.3 296.8 3663.58 3488.58 165207.8 2146690 1931.59 -3666.49 0.32 4144.15 ) ) 6398 73.1 296.4 3690.46 3515.46 165129.3 2146732 1971.46 -3746.1 0.46 4233.16 6493 73.2 296 3718 3543 165048.8 2146774 2011.6 -3827.68 0.42 4324.06 6586 73.1 296 3744.95 3569.95 164969.9 2146815 2050.62 -3907.68 0.11 4413.03 6678 73.3 296.3 3771.54 3596.54 164891.9 2146856 2089.43 -3986.74 0.38 4501.08 6774 73.6 296.1 3798.89 3623.89 164810.5 2146899 2130.06 -4069.31 0.37 4593.08 6868 73.1 296 3825.82 3650.82 164730.6 2146941 2169.61 -4150.22 0.54 4683.11 6962 73.3 295.6 3852.99 3677.99 164650.7 2146982 2208.78 -4231.23 0.46 4773.05 7057 73.1 295.8 3880.45 3705.45 164569.9 2147024 2248.22 -4313.18 0.29 4863.95 7150 73.2 295.8 3907.41 3732.41 164490.8 2147065 2286.95 -4393.32 0.11 4952.92 7245 73.2 296.2 3934.87 3759.87 164410.2 2147107 2326.82 -4475.06 0.4 5043.83 7339 73.1 296.2 3962.11 3787.11 164330.6 2147149 2366.54 -4555.78 0.11 5133.77 7432 73.2 296.3 3989.07 3814.07 164251.8 2147190 2405.91 -4635.61 0.15 5222.75 7526 73.4 296.4 4016.08 3841.08 164172.2 2147232 2445.87 -4716.29 0.24 5312.77 7619 73.1 296.4 4042.89 3867.89 164093.6 2147274 2485.47 -4796.05 0.32 5401.8 7712 73.1 296.7 4069.92 3894.92 164015.1 2147316 2525.24 -4875.65 0.31 5490.77 7806 73.3 297.1 4097.09 3922.09 163936 2147359 2565.96 -4955.91 0.46 5580.76 7900 73.2 297.4 4124.18 3949.18 163857.1 2147402 2607.17 -5035.93 0.32 5670.77 7993 73.2 297.7 4151.06 3976.06 163779.3 2147445 2648.35 -5114.86 0.31 5759.8 8088 73.4 297.9 4178.36 4003.36 163700 2147490 2690.79 -5195.35 0.29 5850.79 8180 73 298 4204.95 4029.95 163623.3 2147533 2732.07 -5273.15 0.45 5938.86 8276 73.1 298.1 4232.94 4057.94 163543.5 2147579 2775.25 -5354.2 0.14 6030.69 8370 73.1 298 4260.26 4085.26 163465.3 2147623 2817.54 -5433.57 0.1 6120.62 8464 73.1 297.9 4287.59 4112.59 163387 2147667 2859.7 -5513.02 0.1 6210.56 8557 73.1 297.8 4314.63 4139.63 163309.5 2147711 2901.27 -5591.7 0.1 6299.54 8650 73.3 298.1 4341.51 4166.51 163232 2147755 2943 -5670.34 0.38 6388.57 8743 73 298.3 4368.46 4193.46 163154.7 2147799 2985.06 -5748.79 0.38 6477.57 8835 73.3 298.3 4395.13 4220.13 163078.3 2147843 3026.8 -5826.31 0.33 6565.62 8929 73.5 298.5 4421.99 4246.99 163000.3 2147888 3069.64 -5905.55 0.29 6655.69 9021 73.6 298.3 4448.04 4273.04 162923.8 2147932 3111.61 -5983.17 0.24 6743.91 9115 73.1 298 4474.97 4299.97 162845.6 2147977 3154.1 -6062.57 0.61 6833.97 9208 73.1 297.2 4502.01 4327.01 162767.9 2148020 3195.32 -6141 .43 0.82 6922.95 9302 73.1 296.8 4529.33 4354.33 162688.9 2148063 3236.16 -6221.57 0.41 7012.88 9395 73.2 296.7 4556.29 4381.29 162610.5 2148105 3276.22 -6301.05 0.15 7101.88 9487 73.4 297 4582.73 4407.73 162533 2148147 3316.02 -6379.67 0.38 7190 9581 73.2 297.3 4609.74 4434.74 162454 2148190 3357.1 -6459.78 0.37 7280.03 9675 72.8 297.7 4637.22 4462.22 162375.4 2148234 3398.61 -6539.52 0.59 7369.92 9770 73.2 298 4665 4490 162296.3 2148279 3441.05 -6619.85 0.52 7460.77 9864 72.7 297.4 4692.56 4517.56 162217.9 2148322 3482.83 -6699.41 0.81 7550.64 9959 73.4 297.7 4720.26 4545.26 162138.5 2148367 3524.86 -6779.98 0.8 7641.51 10053 73.1 297.6 4747.35 4572.35 162059.9 2148411 3566.63 -6859.71 0.34 7731.52 10146 73 298.3 4774.46 4599.46 161982.5 2148454 3608.32 -6938.3 0.73 7820.48 10238 73.5 298.3 4800.97 4625.97 161906 2148498 3650.09 -7015.86 0.54 7908.57 10332 73.5 297.7 4827.67 4652.67 161827.6 2148543 3692.4 -7095.44 0.61 7998.69 10427 73.4 299 4854.73 4679.73 161748.7 2148588 3735.64 -7175.58 1.32 8089.75 10521 73.2 299.8 4881.75 4706.75 161671.5 2148634 3779.84 -7254.02 0.84 8179.73 10615 73.3 299.7 4908.84 4733.84 161594.6 2148681 3824.51 -7332.17 0.15 8269.68 10709 73.2 299.6 4935.93 4760.93 161517.6 2148728 3869.04 -7410.4 0.15 8359.63 10804 73.4 298.4 4963.23 4788.23 161439.2 2148774 3913.15 -7489.98 1.23 8450.59 10898 73.3 297 4990.16 4815.16 161360.6 2148818 3955.01 -7569.71 1.43 8540.65 10992 73.3 296.2 5017.17 4842.17 161281.3 2148861 3995.32 -7650.22 0.82 8630.67 11 086 73.4 295.8 5044.11 4869.11 161201.4 2148902 4034.8 -7731.16 0.42 8720.69 11181 72.9 295.6 5071.64 4896.64 161120.6 2148944 4074.23 -7813.09 0.56 8811.57 11274 73.5 294.3 5098.52 4923.52 161040.9 2148984 4111 .79 -7893.81 1.49 8900.5 11 364 74 294.4 5123.71 4948.71 160963.2 2149021 4147.41 -7972.53 0.57 8986.77 11465 73.4 294 5152.06 4977.06 160875.9 2149063 4187. 15 -8060.95 0.71 9083.55 11559 73.7 294.7 5178.68 5003.68 160794.8 2149103 4224.32 -8143.08 0.78 9173.56 11653 73.5 295.7 5205.22 5030.22 160714.2 2149143 4262.71 -8224.67 1.04 9263.66 11747 73.5 296.3 5231.91 5056.91 160634.3 2149185 4302.22 -8305.68 0.61 9353.75 11841 73.4 296.2 5258.69 5083.69 160554.6 2149227 4342.08 -8386.49 0.15 9443.84 11934 73.6 297.6 5285.1 5110.1 160476.2 2149270 4382.42 -8466.01 1.46 9533 12029 73.5 298 5312.01 5137.01 160396.8 2149314 4424.91 -8546.61 0.42 9624.11 12122 73 297.9 5338.81 5163.81 160319.3 2149358 4466.65 -8625.27 0.55 9713.16 12217 73.4 298.7 5366.27 5191.27 160240.4 2149403 4509.77 -8705.35 0.91 9804.1 12311 73.4 298.4 5393.12 5218.12 160162.5 2149449 4552.82 -8784.48 0.31 9894.16 12403 73.5 299.4 5419.33 5244.33 160086.4 2149493 4595.44 -8861.68 1.05 9982.33 12497 73.1 298.7 5446.34 5271.34 160009 2149539 4639.16 -8940.39 0.83 10072.33 12589 73.5 298.7 5472.78 5297.78 159932.8 2149583 4681 .48 -9017.68 0.43 10160.43 12684 73.3 298.4 5499.92 5324.92 159854.1 2149629 4724.99 -9097.65 0.37 1 0251 .46 ) ) 12779 73.2 298 5527.3 5352.3 159775.1 2149674 4767.97 -9177.82 0.42 10342.42 12872 73.2 298.4 5554.18 5379.18 159697.8 2149718 4810.05 -9256.29 0.41 10431.45 12966 73.1 298.4 5581 .43 5406.43 159619.8 2149763 4852.84 -9335.42 0.11 10521.4 13058 73.3 299.1 5608.02 5433.02 159543.8 2149808 4895.2 -9412.64 0.76 10609.46 13152 73.5 298.8 5634.87 5459.87 159466.2 2149853 4938.8 -9491.46 0.37 10699.51 13247 73.3 298.1 5662.01 5487.01 159387.3 2149899 4982.17 -9571.51 0.74 10790.54 13341 73.3 297.6 5689.02 5514.02 159308.9 2149943 5024.23 -9651.12 0.51 10880.57 13434 73.3 298.1 5715.75 5540.75 159231.3 2149987 5065.85 -9729.88 0.51 10969.65 13529 73 298.2 5743.29 5568.29 159152.3 2150032 5108.74 -9810.04 0.33 11060.56 13622 73.3 298.3 5770.24 5595.24 159075.1 2150076 5150.87 -9888.45 0.34 11149.57 13717 73.2 298.8 5797.62 5622.62 158996.4 2150122 5194.35 -9968.35 0.51 11240.52 13810 73.4 298 5824.35 5649.35 158919.2 2150166 5236.71 -10046.71 0.85 11329.59 13903 73.1 297 5851.15 5676.15 158841 .3 2150210 5277 .83 -10125.7 1.08 11418.64 13998 73.2 296.9 5878.69 5703.69 158761.4 2150253 5319.04 -10206.75 0.15 11509.56 14094 73.2 296.7 5906.43 5731.43 158680.5 2150297 5360.48 -10288.78 0.2 11601 .45 14187 73.1 297.8 5933.39 5758.39 158602.5 2150339 5401.23 -10367.91 1.14 11690.46 14279 73.3 297.2 5959.98 5784.98 158525.5 2150382 5441.9 -10446.03 0.66 11778.53 14374 73.5 297.8 5987.12 5812.12 158446 2150426 5483.93 -10526.78 0.64 11869.57 14466 73.2 297.2 6013.49 5838.49 158368.9 2150469 5524.63 -10604.97 0.7 11957.71 14560 73.7 298 6040.26 5865.26 158290.2 2150513 5566.38 -10684.82 0.97 12047.82 14654 73.2 297.5 6067.04 5892.04 158211.6 2150557 5608.34 -10764.56 0.74 12137.92 14747 73.6 295.6 6093.61 5918.61 158133 2150599 5648.17 -10844.28 2 12227.03 14842 74.1 295.2 6120.03 5945.03 158051.7 2150641 5687.31 -10926.71 0.66 12318.21 14937 73.7 294.8 6146.38 5971.38 157970 2150681 5725.88 -11009.43 0.58 12409.39 15032 73.4 294.6 6173.28 5998.28 157888.3 2150722 5763.96 -11092.21 0.37 12500.39 15127 73.4 294 6200.42 6025.42 157806.4 2150761 5801.42 -11175.18 0.61 12591.29 15220 73.2 295.7 6227.15 6052.15 157726.6 2150801 5838.85 -11256.01 1.76 12680.26 15314 73.5 296.2 6254.08 6079.08 157646.7 2150843 5878.26 -11336.99 0.6 12770.28 15406 73.3 295.7 6280.36 6105.36 157568.5 2150883 5916.84 -11416.26 0.56 12858.42 15499 73.3 295.4 6307.09 6132.09 157489.2 2150924 5955.26 -11496.63 0.31 12947.44 15594 73.8 295.5 6333.99 6158.99 157408 2150965 5994.41 -11578.9 0.54 13038.49 15688 73.9 295.3 6360.14 6185.14 157327.5 2151006 6033.14 -11660.46 0.23 13128.72 15769 73.5 295 6382.87 6207.87 157258.1 2151041 6066.18 -11730.83 0.61 13206.39 15880 73.1 295.8 6414.77 6239.77 157163.3 2151089 6111.78 -11826.87 0.78 13312.63 15974 73.4 296.1 6441.86 6266.86 157083.5 2151131 6151.17 -11907.81 0.44 13402.61 16069 73.1 297.1 6469.24 6294.24 157003.3 2151174 6191.9 -11989.15 1.06 13493.57 16165 73.2 297.5 6497.07 6322.07 156922.8 2151218 6234.04 -12070.79 0.41 13585.44 16353 73.2 299.2 6551 .41 6376.41 156766.8 2151308 6319.5 -12229.18 0.87 13765.39 16447 73.3 299.4 6578.5 6403.5 156689.5 2151354 6363.55 -12307.67 0.23 13855.36 16539 73.2 300 6605.01 6430.01 156614.2 2151400 6407.2 -12384.2 0.63 13943.4 16632 71.7 300.7 6633.05 6458.05 156538.9 2151447 6452 -12460.72 1.77 14031 .96 16727 71.5 301.3 6663.04 6488.04 156462.9 2151495 6498.43 -12537.98 0.64 14121 .94 16786 70.9 301 6682.05 6507.05 156415.9 2151525 6527.32 -12585.78 1.13 14177.68 16899 70.5 301.2 6719.4 6544.4 156326.1 2151583 6582.41 -12677. 1 0.39 14284.13 16994 70 300.9 6751.51 6576.51 156250.8 2151631 6628.52 -12753.7 0.6 14373.37 17030 69.7 300.9 6763.91 6588.91 156222.3 2151649 6645.88 -12782.7 0.83 14407.11 17089 69.3 301.2 6784.57 6609.57 156175.7 2151679 6674.38 -12830.05 0.83 14462.27 17179 68.5 301.6 6816.97 6641.97 156105.2 2151724 6718.13 -12901.72 0.98 14546.04 17276 67.6 301.9 6853.23 6678.23 156030 2151774 6765.47 -12978.22 0.97 14635.77 17369 67.6 301.9 6888.67 6713.67 155958.3 2151821 6810.91 -13051.22 0 14721.51 17464 68.2 303 6924.41 6749.41 155885.3 2151871 6858.14 -13125.49 1.24 14809.2 17555 68.4 302.6 6958.05 6783.05 155815.5 2151918 6903.94 -13196.56 0.46 14893.4 17648 67.7 303 6992.82 6817.82 155744.3 2151967 6950.66 -13269.07 0.85 14979.29 17745 67.2 303 7030.02 6855.02 155670.5 2152018 6999.45 -13344.2 0.52 15068.47 17840 66.5 303.7 7067.36 6892.36 155598.9 2152068 7047.47 -13417.16 1 15155.37 17932 65.7 304 7104.64 6929.64 155530.3 2152116 7094.32 -13487.02 0.92 15238.98 18027 64.7 304.4 7144.49 6969.49 155460.3 2152167 7142.8 -13558.34 1.12 15324.63 18120 64.3 305.1 7184.52 7009.52 155392.7 2152216 7190.64 -13627.31 0.8 15407.91 18237 62.5 306.1 7236.91 7061.91 155309.3 2152280 7251.53 -13712.38 1.72 15511.49 18311 62.2 307.5 7271.25 7096.25 155257.9 2152320 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'" tß,) \':> <..<:..ü.~\~ '<li.ccc ~'~~\\.\\"\ \).) i~>\"~~t!.~ w"'"'i <.t;",ì \)~\\<J.\;S.~ o~ <..'""~ \>~~ (ß) \~T'.)~"'<:..i:.. J... s~~ -\c ~'-.)Q: (t),",,\,~J ~ 'S, I Cl '\ ~~<'! ~ ~ ,-'ð x::\,\ t--Q C).-\-'\~ '" Re: 1 ~~ [Fwd: .~ 15RD 5T1 L 1 ) ) 130 ~-lS-l Ç).O ~~'- ~$. \CJS '.'0) ()~~,,~~ ~Q\\ ~\.)~~'oQ: ö-~~~~t;.~Ctd ~Q:,~~ \\.\ \<"t. <I'r\() ~ ~ '0 '-.} '"' \ (L S "'::, ~<:L \ \. \:. "-> <.s:>~? \\(.~~ 0 '" ""~." \)<è.~ ~ 0__ O\><L\U.~'\:C~~ ö-~ ~\) '''' CJ..<:"'~~~~<ë. ~I a-s ..<-.J~ d- inadvertent sidetrack] l () \) [~ í' LßO~- (eJ "-319- Fo 62- w-A If-<.-fJ 7Õ f/f;1J·P--l Nh S-DO :; {;¡A. ¡V K J 31L-L XV...I r.:L mlM tIO?/? l/?O MT)УP/'.J ()r AAlY (9 I') e: o-rH£ÞL r"£\!' ék> E Þ lit E;. W --¡fiE:. Mt¡.JOtZ.. 1% SHo£ I ¡J1£Q.t:S'l I JJ F/2·&VV1 rrlió M Iò NO -rf. ,..1. nt£;. plZÐ b a-A ¡VI (;eo L-C> [, I "- ÞA íA -rruz f) (). (,/-IÐl.-'1" 1:, EI2..E A ¡¿E i'J 0 It-I 1$ w£U-,,8o{(E. Y&1A We. I ù£ 1Ñ6 uifl-l- Ð-rtætL- II t. :tßN-&5 RE::4 sf:- CþL L- t::Lr:;A-S E ""ReV I Ðù <f e.-,<¡- , }Ðu (!AN. :r '/!/1 T7ä) N& t¿ eo 51" 'P(CD:r~ 1í 0 Al_" C3 U í 0 f 1<'f.1 () W WI/A"" we W, u... A.J eEÞ ~~ (pET A l t!Ð--ut s Ø' to :þ 0 N4 N /) (ß- (JJ AJ u,v-rJ L I -~·7·~; ft/? ME A ("" .. ~ 561·(9 N AS /") (:~ P A"0 e~) -t- ~o VEIL. 1· .-~._) "') .....-- -: '~~~_'J ~ /-/A AlSEA) S::Uç:PE¡J~IO~ t ....,..--- ~ Jv )() 12ÐM 13 ) IV MIf-u ¡J D E12- J L.L LLoYD ,) RECEIVED MAR 1 2· 2002 Alaska on & Gas Cons. LomfnlS~;¡1 it AnchoraQP (. ) ~ BilllIoyd Phillips Alaska Ine YV~1 . .. LO ml¡\\ 171ëf7. / 7. 1 / 7. o Without question. if feasible, we would like to avoid cementing as a well suspension option. In order for us to move forward on finalizing our plan, I would appreciate your input. Thanks .astly we could set a CIBP on eline immediately above the upper packer. Because the perf guns are still attached to the tailpipe below the upper packer. we cannot aecess the Tyonek interval without milling up the packer. We do have 2 joints of slotted liner below the packer however, prior to suspending our testing operations, we performed an injectivity test into the Tyonek and achieved a rate of -3 bpm @ 3900 psi (0 84 psilft trac gradient. Although it is feasible to pump cement through our tailpipe and bullhead into the formation, this would create significant problems in the event we wanted to re-enter this zone for additional remedial work. Set I' . :md NU BOPE. Pull BPV and test RU ,:~ (i pull 3-1/2" PH-6 tubing and accessories from PBR above 9-5/8" pad :: D. LD tubing and accessories via laydown machine. W": ': ~ II HT-38 drill pipe currently stood back in derrick. PU :) I Ird EUE kill Set ur' I II n~lalll'...... u........ 1IòO.,U :;(DMO Nabors 273. 6) '7) 3) 4) 5) DDV, ND BOPE and NU and test tree handles from ~r""å ........n .........J remove all tree and secure same. string and RIH ~. '§>Q;~.. ~ \? ~~"Jq~(_\-:.rf~- ~~~~~",,~.\\ ~~ '-~ ~~ 1) 2) BOPE to 5000 psi. OB.JE:CTIVE: Phillips Alaska Inc desires to temporarily suspend this well for up to 24 rnonths to evaluate well data collected during the test, and to evaluate further cörnpletion/testing potential. At this time it appears reasonable to believe Phillips may I within that. time period, re-enter the wellbore as a sidetrack candidate. With that in mind, our prefelred well suspension program would be as follows: Well is currently 51 with tree installed and tested. Tubing and 9-5/8" x 3-1/2" annulus ha$ '''13 ppg fluid (combination diesel and crude used for jet pump power fluid). Due to tigtltlddmaged reservoir, the well is unable to flow. Calculated GOR from Hemlock and Stark·jll<off zones is -160 SCF/STB CUfrent Profile: Well has two packers; one above the Hemlock @ 17502' and one above thd Tyçn'¡ek @ 16525', Both zones have been isolated with a PRN plug in a nipple profile below each packer and both plugs have been tested to -3700 psi. See attached $Ghematic E)(tênd~d Well Suspension Program Hansen #;'1 Alaska ( t~ )~I~ ,J .1 ,~·,'.4,\j : CøAi F/~A17Í A¿~ ) MAR 1 2 2002 RECf ) , VFD 02/12/2 4 WED 7 : :~ fAX )- ) ÛСJP:-(P8/JuA0 HANSEN #1 CURRENT CONFIGURA TJON j L 2rJ' Conductor Cæh1g Set @ 693' At ... 13·3/8" 72# l-80 Sl Boss Set @ 5184'MD/3341' TVD 9-5/8" SAB Packer Set @ 16525' MD/6601' TVD Z Z Tested to 3800 psi 1 þm slotted iner 18589 - 98 Z ~ ~ PRN Plug set In RN nipple @ 16567' MD/6642' TVD 1111,1 Pressure Tested to 3750 psi f130 mln 9-518" l-80 Sl Boss ... ~ 47# to 16825' MD -10034'16695' - 4742' TVD 53.50# to surface 1 joint 3--112" slotted liner IIIII 16833 - 63 ~~ - - Tyonek Perf Interval: - - 16694' . 17194' MD - -r-" 6653' - 6622' TVD 6 - 0.38" dlajspf@60 degree phase Z Z 7" BaI<er SAB Packer Hemlcok Pert Interval: Set @ 17502' MD16938' TVD 17915' -17555' MD Z Tested to 3800 psi 7098' - 6958' TVD - - PRN Plug set in RN nipple - - - - @ 17544' MD/6954'; tested to 4000 psi f/10 mins - .. ~ 7" 26# l-80 SLHT Set@ 18625' MDf7417' TVD TOL@ 16629' MD/6632' TVD ) RECEIVED MAR 1 2 2002 Alaska Oii & Gas liÙII::i :,)UI ....:-:. Anchorao r~] :~ UZ/1Z/ZU14 WhlJ U'{: 3 ~'AÅ I· ') ÛСJ r:: tp t?!JVA. 0 HANSEN #1 CURRENT CONFIGURATION .)1<. ~v'" L 20" Conductor Casing j Set @! 693' '-- ~ dOf:X:)~ \.:.:-, \\ ,::An~  ~ 13·318" 72# l-80 Sl Boss Set@ 5184'MD/3341' TVD 9-5/8" SAB Packer set @ -ZZ 16525' MD16601' TW Tested to 3800 psi 1 /01.. .1otted ßner 16569 - 96 Z :g X PRN Plug set In RN nipple @ 16567' MD/6642' TVD IIIIII Pressure Tested to 3750 psi fl30 mln 9-5/8" l-80 Sl Boss ...-II .... 47# to 16825' MD -10034'/6695' - 4742' TVD 53.50# to surface 1 joint 3-1/2" slotted liner III1I 16833 - 63 ~W - - Tyonek Perf Interval: - - 16694'·17194' MD - - 6653' - 6822' TVD 6 - 0.38- dla jspf @ 60 degree phase ~ :g 7" Baker SAB Packer Hemlcok Pert Interval: Set@ 17502' MD16938' TVD 17915' - 17555' MD Z Tested to 3800 psi 7098' - 6958' TVD - - PRN Plug set in RN nipple - - - - @ 17544' MD/6954'; tested to 4000 psi fl10 mins - - ~ .. 7" 26# l-80 SlHT Set @ 18625' MDfT 417' TVD TOl @ 16629' MD16632' TVO I{!,I "" ,1 ) RECEIVED MAR 1 2 2002 Alaska Oil & Gas tOilS ;.)() ¡:-,!-:. (\ Anc:hora(1t· of 1 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 3/11/022:14 PM Tom Maunder, PE Sr. Petroleum Engineer AOGCC ~ It seems clear that the liquid wastes you have described are eligible for annular disposal. Good luck with the operation. I will send a fax of this to the rig at 399-5009. [...Since the original request was received, PPCo has requested clarification of AD eligibility for wellbore cleanout fluids (diesel/xylene/spent acid) and produced fluid storage tank cleanout fluids. 20 AAC 25.080 (h) (1) lists wastes eligible for AD and includes... "completion fluids, formation fluids and any added water. " .] Bill and Paul, This note is in response to your request for clarification regarding the wéllbore cleanout fluids (Diesel/Xylene/spent acid) and the tank bottoms and cleanout fluids from your test tanks. Below is a portion of the document I prepared reviewing your annular disposal application. Subject: Hansen Cleanout Fluids and Tank Cleanup Date: Mon, 11 Mar200214:14:11-0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: BilllIoyd <wlloyd@ppco.com>, Paul Mazzolini <pmazzol@ppco.com> CC: Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us> Hansen Cleanout Fluids and Tank Cleanup é7ù \-\S¡ 02/01/2014 SK[' 04:42 FAX [it] 0 () 4 / -' . <j)¡n-.' 2 - !z!3' 0 2 ---. ~ 1/14 ~. )0" t 0 It1 IV ('. - '.'(1/tJ iJ r:::; 12- A06C[ ~-1o/t : B ILL ~YlJ 11-11 iLl Þ S' ) . . ~,,..r!~~~M"'" ~{\' n..'.ë. y(: ~~, f: ~,,~ K~" L ,. F~") ~ tr1i 2'1'1 - 51ó I to :" 39q - 51...,0. '.' oo~aØj."¡Jtt.lflfì.-Chns. Commission .:~., C" Antfiofage rf/- ' r<]c ~ ¡! AlIJ U LA R- VIS PDSA L /J1íE. v'S. P£.t::--SSUI!É 12m 1~4 Æ/SEIJ #"/' 13 3/ e;' x q 0/&" .4 N t\!uLU5 --¡¡; IV/. A 5 , *I2E 5" mE- RAft: vs. f:?/ê,ES'SUICt::.· ~/,,,-D ~r IAltzt4L 13fZ&Aléf)fJ];¡(}AJ FOIL /jÁ/Æ}{JL..4¡;':: fÓlL. t9t{((- ~¡Sí-::t;5AL ~ ON A S'EPAlf:At6 A/OT~ toE ¿:-::/1/!:.) (::._!.) t¡þ 4 290 7õrAL B8CS (JJF SPENT A<=-lc.D tù.¡.((ul 1145 ßEEN /\/t;;:urKALIZEJ) 70 pI! /:0 Av() R(ÇiAI)Y' íÚ 60 y¡; -rUE Sr.b«F4(_E Fkcst! MÆR.. ('ez_c Aí. VOLt¡¿ A PPR..DVAL. L.øv/é. FVlétu4¿'i) To #¿:,;qf(~/ttf FRolv( YDU, 7fiÃf./K5 _ . · G 131 LL -- Þ< <:: ~ N ..r ..r o ~ rn ..r ...... Ñ "- ,....., "- N . . ._~ -.~ ..:\~. ~. "." . " -. .' "'~-'. '.~II"~'. ,.. "" ',': ,... '-':. . >:':. . . "- . ~i 'R.:a- - - - - . . . - . ;'·'r~;,~t'!:"·~h:t'~t;·;t,·:t:~:~~:t c æ:);~!j;t;;!ff;)t~fi~;~té-t¿~?~~i¥t~~~~:l:l?J..tCt:J;.~til;·.....:,.1....:,... "þ,.,."......." .~ ....I-,.-!...'-"....-~"'"'~:.~. .~~þ...I':L~~l r_~I.,I_'t-!'":-J:v '_'_"""~"""'_I~~ '_._ .. "." . . ..'- .... .. i1~~t~ff11~f;t ~jšrl~iftl~¡:f "".' .-,.,-it""'''-...........,... .'0- .--. ...,..' ". m..... '. jŒ~~q .. i .~. ¡ . j ì·r;··:~:..}:.; r l' ~ ~ ·.r··!' r - ¡ ·'-i .': .r'1-· :' f . ¡ i . " iLl... ¡ ~ ' .' .', ," . '. " . . . . . .' . ! 1 tt ¡~(jlt+kl:t.l.¡ ! . ! 11J . ... ..' ~ . . . " j....J:( -.' .}.t·l.:··i 'f" .-., .' ,;'f'-:':¡': ..;:~ 1-, r·:l ·r i t YL4 ~.' ;~~J.d ..i.J ·~r~~ L . r.' .. '.. . . :' u.~iea.;iÎ:Jf*J,: J . '.. ." ~~. ., . .' I ,.......... :,~. ,':. ..."':"....... J:-. -~ .. . . ... ..,.. 4_ · "_.3 -, · r ·1 . ~~- K . ~ , I J'U V) I ~ ~ 1- ~ 0 ~ g ) o C/ C r.N iC ::- ~ þ.¡j{ .,' l r~ /A:)';~ ,-J i c>' J . ." , flu f41.f PU'*tÞ.RÀ tE . -: -/spÜ·'· ~ #~ : ,;;.~": :./:~r-. ~.~ . ., --~ - '. ·r' _ ~ _ . . -. - ". -L- n a·'~":..··, '. ";~.·~~'v J,? .../ . ?'~<.. I ¡;.0- J.: c:;¡..;;.;:,"'...... ............... I I .....". :, .. .~J . '. - ~ ".'. ~_ . /::'¡.. _ ::~..è:¡~~~·)~t:' ...... . '. ,;"',.. -'. ..,.:...... . : -.' . .-, .-.'.......::. .",-.'. '. '- -'. ·.·~,;jY~à~~tit~~t,i~þ ·çf~~~.i{jj~"~~~,;c··i~¡4¿~;o~20r:~Ð~~' ;. -. :":"'-. ~~ ..- : - ~ . . - ) ) ¡l1~ J /'1', P Wtit,:~' \ \/0 II NOTE TO FILE PPCo... Hansen #1...201-157...302-006 In early January, Phillips (PPCo) requested permission for annular disposal (AD) for their Hansen #1 well located on the southern Kenai Peninsula. In addition to the "straight" AD request, PPCo also requested approval to dispose of up to 75,000 bbls and in advance of the formal approval of their request to dispose of snow melt/rain water and water base drilling fluids on site. The purpose of this document is review their submitted information and make recommendations with regard to their requests. The Hansen surface location is about 500' inland from Cook Inlet and the well was drilled to an offshore target some 3 miles offshore. The proposed disposal annulus is the 13-3/8" x 9-5/8". The 13-3/8" casing shoe is at 5177' md, 3339' tvd and some 2100' offshore. The casing was successfully cemented to surface with a 2 stage operation. The 13-3/8" casing was the 2nd casing set in the well. 20" casing had been previously set at 698' md/tvd and cemented to surface. The 13-3/8" casing was successfully pressure tested to 3000 psi. After drillout, a formation integrity test was conducted to 13.0 ppg EMW. The test was not taken to leakoff. After drilling the intermediate hole, 9-5/8" casing was set and cemented at 16826' md, 6695' tvd. The casing was pressure tested and passed the 100/0 loss criteria in 30 minutes, however the pressure loss did appear to be stable. Conversations with the on site supervisor indicate that when the 7" liner was set that the entire wellbore was successfully pressure tested and In subsequent jet pumping operations, no problems have been reported. After drillout the formation was tested. A maximum of 12.8 EMW was reached, although it appears that initialleakoff was at about 12.3 EMW. As noted, Phillips sought approval to dispose of rain water/snow melt and water base drilling fluids in advance of this formal approval. Such an approval is possible when the TDS of the planned disposal fluid is determined to be less than the TDS of the formations exposed below the 13-3/8" shoe. PPCo provided logging data from the wellbore indicating that the intervals below the shoe had salinities in excess of 6000 ppm TDS. Given the offshore location of the casing shoe, the tvd and the determined salinity, it is not practical to consider any waters encountered as having a potential for human consumption. PPCo's request was approved and disposal has occurred. According to the records of the initial pumping operation, they pumped 540 bbls of rainwater/snowmelt at a stabilized pumping pressure of about 1040 psi. Examination of the provided pressure plot shows that formation leakoff occurred at slightly over 1000 psi, in good agreement with the stabilized pressure. Based on the casing TVD and assuming 8.3 ppg fluid, the formation(s) accepted the fluid at 14.3 EMW. This is in excess of the determined FIT established when the '\ ,. t ¡ shoe was tested on drillout, however the pressure plot is stable and does not indicate that the disposed fluid is moving to a shallower depth. PPCo further requested to exceed the waste volume limitation of 35,000 bbls. The basis of their request is the large hole sizes drilled for the well as well as the potential for rain water and snow melt accumulations in the storage pit. This request is not unreasonable. The calculated gauge "earth" volume of the holes drilled to the 9-5/8" casing point at 16826' is nearly 3500 bbls. When processed for disposal, it is not unreasonable for the "earth" volume to increase 10 times when converted to a pumpable slurry. PPCo's request of up to 75,000 bbls is .--- . appropriate when the hole geometry an~o~ental fa~s considered. Since the original request was received, PPCo has requested clarification of AD eligibility for wellbore cleanout fluids (diesel/xylene/spent acid) and produced fluid storage tank cleanout fluids. 20 MC 25.080 (h) (1) lists wastes eligible for AD and includes... "completion fluids, formation fluids and any added water...". In compliance with 20 MC 25.080 (e) (1) (B), notice of a public hearing was published on January 17. No request for hearing or any comments were received. Based on review of the supplied information, the following is recommended: 1. It is recommended that PPCo's request for AD into the 13-3/8" x 9-5/8" annulus of Hansen #1 be approved. 2. 2. It is recommended that PPCo's request to exceed the volume limitation of 20 MC 25.080 (d) (1) be granted. Unless otherwise specified the volume limitation for the Hansen annulus is 75,000 bbls. 3. Approval to exceed the downhole pressure determined from the integrity test below the 13-3/8" casing shoe is recommended. No leak off was achieved with the initial test. The subsequent test indicates that the formations accepted the waste at a constant pressure and upward growth or movement is not indicated. 4. The cleanout fluids identified in PPCo's latest communication are eligible for disposal into the annulus. ~~~~J~ Thomas E. Maunder, PE ( Sr. Petroleum Engineer ----. ~ ~ 02/01/2014 SAT 04:41 FAX ræOO.l j f ø .' l ""7- ;.. --' -- -!!'d. ..: -.I ~ c2 J:;Þ ') -;; ~ U,w ,uÐéR- fi&/Vl : 8, LL L4¡fJ AAt~ e $ -+ C Ð tJ'"6"rZ, ~ 3 i¡\ r'o \1 ¡¡.... '\ . " mn\\SS\on .. & ("aß cons. lJQ f\\asl<.a 0\\ 'þ;\cnotaga 1;;;n J HzA sF 12£ 7Ú IlAJ ¡=:Ax c;J 3'7 ~ · S 009 LA l£. ¡Ut£ @ ;( 'I Y ,. 56 16 . -;:;;4 J!cS" t9rt-- Q UILL· 02/01/2014 SAT 04:41 FAX r4J002 \ Date: February 25, 2002 To: Tom Maunder, Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission From: William lloyd, Sr. Exploration Drilling Engineer Phillips Alaska, Inc RE: HCUXylene Mixture for Annular Disposal Hansen #1 Dear Tom, As part of our ongoing exploration drilling program on the referenced well, we are presently planning to do a coiled tubing cleanout of our 3-1/2" tubing string and the annulus of the 3-1/2" tubing and casing. The purpose of this cleanout is to eliminate the problems that have been caused by calcium carbonate solids that was used in the drilling fluids. In order to eliminate this problem, we will be washing through the tubing with a mixture of diesel that has been used as our power jet pumping fluid and 15% HCL and xylene. There are two components to the additives to the diesel. One will be 75 bbls of total volume made up of 15% HCI and 25% Xylene and the other win be made up of 25 bbls of straight Xylene. As the HCI comes in contact with the CaC03 in the wellbore, it will "spend" and become C02 and water. Per our conversation this afternoon, Phillips Alaska Inc requests approval to put the returned, used fluid into our surface invert storage cell as part of our fluid mixture for annular disposal. Please advise if this fluid can be mixed with the invert emulsion oil based fluid and cuttings in the storage cell for future annular disposal in the Hansen well as part of our approved Sundry for Annular Disposal. ... -. § , DISPOSING INTO ANNULUS OF WELL: I I PUMP STATIC ORIGIN OF START RATE PRESSURE FL.UIDS TIME END TIlliE (BPM) (PSI) ,,.'----. Reserve Pit 20:0{) 0:00 2 1000 .~'""- ;.< ~ ~ ~ ~ o ~ ~ ~ INIGHT DISPOSAL. SUPERIflSOR: ..... C :N "" ..... "" N o VERSION 1.3 RJ~~.f ~ r;-·t PAt .. DAILY ANNULAR DISPOSAL RECORD I 1 NABORS 273 HANSEN #1 DISPOSAL. PRESSURE (PSI) OpenrtIonthat g llneratert waste Mud 1040 Drilling TOTAL VOLUMES FOR DA Y: I ADDITIVES USED: BARRELS DISPOSED (List under øroøer fluid tvøe) Mud WATER for F\Ulhlng Annulus MUD WATER GEL NIGHTS , DAYS 'DAY DISPOSAL SUPERVISOR: DIESEL. for I Freeze Rig Wab Prote«:tIÐg Water DJESEL WASH WATER I I Q.GEL X·1ND PAl DAlL YANNUlAR INJECTION RECORD DATE: ; OTHER (specify In çomment8) Water OTHER 540 BICARB 1 TOTAL CUMULATIVE VOL.UME 540 Total for Today 54D PH6 1f13/02 ??oo TO 0000 HRS FOR MUD ONLY: WEIGHT FUNNEL (ppG) VISCOSITY CumInuICIvø TotiIII from PT8vious Day o IPHlL.UPS SUPERVISOR: PagE- _ of_ COMMEN'ß Water from WBM reserve pit NIW Tot./lI for this AIInulus 540 SCOTT D. REYNOLDS 12-20-01 ~Q r: (. \ t' ¡ i I ,... i"'lf¡ '}" ,t,.. tw, ,(i ~ i .t"- § J.. '¡ k.. '.' ~'. :i~f Ff:6 ? 5 2d02 't!~-!SfÚj [),; iJ; r9¢-. 14.1001 ~ {;5, ¿.L-.. kin ) 'f£.cA.&E rz¿Tú,e/J p:'.lJy r;;J 5'7q ~ S- 009 cA '-£-,. ¡!/l~ @ ~ 'I y,. Shlb I íil4 J/c:..s ~~ c2 /::2- CS'/ 0 ")/ -¡;; ~ ;U/IitIIVDE1Z- ~&tY1 : 8, L-L ~(J Fkt~ e $. -f. C Ð UT~7Z__. :- 3 ...1 l ) ) 01/28/2014 TUE 07:55 FAX 01/28/2014 TIJE 07:55 FAX @ 002 ) ) Date: February 25,2002 To: Tom Maunder, Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission From: William Lloyd, Sr. Exploration Drilling Engineer Phillips Alaska, Ine RE: HCL/Xyrene Mixture for Annurar Disposal Hansen #1 Dear Tom, As part of our ongoing exploration drilling program on the referenced we", we are presently planning to do a coiled tubing cJeanout of our 3-1/2" tubing string and the annulus of the 3-1/2" tubing and casing. the purpose of this cleanout is to eliminate the problems that have been caused by calcium carbonate solids that was used in the drilling fluids. In order to eliminate this problem, we wit! be washing through the tubing with a mixture of diesel that has been used as our power jet pumping fluid and 150/0 HCL and xylene. There are two components to the additives to the diesel. One will be 75 bbls of total volume made up of 15% HCI and 25% Xylene and the other will be made up of 25 bbls of straight Xylene. As the HCI comes in contact with the CaC03 in the well bore , it willl'spend" and become C02 and water. Per our conversation this afternoon, Phillips Alaska Ine requests approval to put the returned, used fluid into our surface invert storage cell as part of our fluid mixture for annular disposal. Please advise if this fluid can be mixed with the invert emulsion oil based fluid and cuttings in the storage cell for future annular disposal in the Hansen well as part of our approved Sundry for Annular Disposal. Wilham. I d~ Co: Paul MazzoÛiì ~ & PAl - DAILY ANNULAR DISPOSAL RECORD Page_ of_ RIG #: I NABORS 213 DA TE: I 1/13/02 OOOC TO 0000 HRS DISPOSING INTO ANNUL.US OF WELL: I HANSEN #1 BARREL.S DISPOSED CUst under prOPer fluid type} FOR MUD ONL.Y: PUMP STATIC ORIGIN OF START RATE PRESSURE FLUiDS TIME END TIME (BÞM) (PSI) ~- Reserve Pit 20:00 0:00 2 1000 DISPOSAL PReSSURE (PSI) 0peraU0n that genel'8ted Waste Mud MUd WATERfør FluatJlng Annulus DIESEL for Freeze I RIg Wuh Protecting Water OTHER (apecIfy In comments) TOTAL CUMULATIVE VOUJME WEIGHT FUNNEL (PPG) VISCOSITY ; COMMENTS 1040 Drilling Water 540 Water from WBM reserve pit ,.-. t-- Cummuterlve TotItI trrJm NaN TOtsJ forfhí8 Anrrulua Total for Today PnNIous Day MUD WATER DIESEL WASH WATER OTHER TOTAL VOWMeS FOR DA Y: I , I 540 540 0 540 ADDmVES USED: GEL Q·GEL X- TND BICARB PHS NIGHTS DAYS 'NIGHT DISPOSAL SUPERVISOR: IDAY DISPOSAL SUPERVISOR: IPHfUJPS SUÆRI/fSDR: ~ ~ .... ~ ~ o r....... - ~ ..., C\1 "- co C\1 "- -. o VERSION 1.3 PAl DAILY ANNULAR INJECTION RECORD SCOTT D. REYNOLDS 12~20-01 Hearing ) Subject: Hearing Date: Thu, 31 lan 2002 19:07:45 -0900 From: lody Colombie <jody_colombie@admin.state.ak.us> To: Camille 0 Taylor <cammy_taylor@admin.state.ak.us> Cammy, there is a hearing scheduled for next week February 7, 2002 at 9:00 am. It is a hearing on annular disposal for the Hansen #1 well. The operator is Phillips. Is this hearing going to go forward? As far as I know, no objections have been filed. Jody r~~~~6k~d~ ~ 1 of 1 1/31/027:07 PM ì \ ) ,\ Anchorage Daily News Affidavit of Publication 1001 Northway Drive, Anchorage, AI< 99508 AD# DATE PO ACCOUNT PRICE PER DAY OTHER CHARGES OTHER CHARGES #2 GRAND TOTAL 276382 01/17/2002 02214019 STOF0330 $156.18 $156.18 $0.00 $0.00 $0.00 $0.00 $156.18 $156.18 STATE OF ALASKA THIRD JUDICIAL DISTRICT Lorene Solivan, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and durmg all saiâ time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexeâ is a copy of an advertisement as it was puólished in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of saId period. That the full amount of the fee charged for the fore~oing publication is not in excess of the rate charged private inchVi~:t /' Ie (ì ( Signed d C C\¡:ilAJ,Jè= '- Notice of Public Hearing. . . . STAT I:; OF ALASKA Alaska Oilan.d G.as Conservation Commission Re: ~PPIi~~~~~I~~t~~~U~~~e~i~~~~llIof Drilling Phillips Alaskålnc.,bYapplicatiandatedJI:Hìuå~Y·. . 7, 2002, has requested authorization to dispo~e of drilling waste .through the annular space o·f the' I Hansen. #1 well' in accordance with20AAC 25.080. Subscribed and sworn to me before this date: ( /17/92- Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska . 1 MY COMMISSION EXPIRES: 29þ5 4/ (¿ A,j. i I, '.., "I Drilling.waste rnciynolbe disPos~diii'an inførwal' that contalns.fréshwat(:!r un less .thecommlssIon finds that thefres~water has cnotal dis-SaINeQ5QI-',.:. ids conten~.of n'l0re thai13,000 mg/l,andisl1otreç¡- . SOn~~IY expected t~ s~pplY a puqHc w~ter.s\yste!'!):'1i The sUrface location. of the,Hansen #.1 well Is 2148', from the so·uth nne &. 1527'·I",:·n, thE' ",,,,¡t lir... So!'¡:-' tlon 2· T~S', R15W Sewal"a 1,Ie-flallln. Th.;. PI"". t·O')';-(I ,nl",r.OI lor a;')t'o~ol 0' (lI"illln9 lII'OS''''e. i, 010 de-pin 01 Hjÿ TOIOI .....rT,COI DE'IJln "ppro~ imIJT';-I, ':'101) 01'')1'101"'" COlculc"'",a ')ollrlll·. .0IL,,?;' lI"orl'1 log meO";i;rE'm;;;nts t(lk€,r, ·,·vhllp. ärallng' conS"'I"·.ot;...I,' ;ndl(OIt' 0 ')Ol,nlly ot 6000 DOrl') Deol" millial1 01 The ~ur I(lC"" co')lng >l'Iü'!' A person'J11ciy .SI.lÞ~¡t\lVr.Itten comments regard" .1 In9 thl$.requ¢sthQJat.erithan 4:30 pmon febru.ory,: 7, 2002.to the Conservation COrnnjisslqn a.t 333 West' ':! -Ith A','..nuE' Sua.¡.·100 AnChol"og.. .~105ko 9950".' In ': oadltlon. Il'Ie C"mmll;slon 1'10') tPI'ITOII/,!,I,. set (I Dub- : lj,:nI:-IJrin.¡¡ or, Ft-bruar, 7 2002 IJ' 9.(00 om 01 It.", Ala~I<a.O.1 ona I:;os. Cono¡,e-I".ot,c,n Comml').,on 01 333. West:7tn Mvl!'I1lJe. SUi I", 100. ':'n(I'IOl"0ge Alo')ka 99501. A person'may requestthatthe te.lifativelyi . scheduled hearing be .held by. filing a written.'re·· . quest With the Commlsslonprior.·toFebruciry l¡, 2002.. . I . ..' .'.'.'.:,. ... .... .,.....,., . ,,' If a request for cil'1earingisnot timely filed, the Commission will consider the issuance of an order· without a hearing, To learn. if,theCo.rnmi.ssíon will hold the public hearing, please<:aI1793-1221.· II you are a person with a. disability who may need a. special modification in order to comment or to attend the public hearing, please contaCt JodY Co~ ramble at 793"1221 before February 1,2002. CammyOechs,," Taylor C.hair :~ 'PUblish1-January 17, 2002 \\ll(((((((II'/: \,\\ ~\:\~.~: O~""rr. ~\:. 0".' --_ · ."T~ ~ S ~·+OTA/fj:.~~ ,:::. --- ........ ... . bI. .r_ . ::: = ~ : '--USLIv : ::: =...z:.eI!.. ___~.,~~ - . ~ . ~........ ~~'~Q=~ ..'~'~ ~ · '. . · · ._A :\V /.1 Su:*tJ& P~" :I.I})) J) JJ)\ \ \' RECEI VED JAN 3 0 20\!/ '.! :~sl(a Oil & Gas Cons. (;ommisSior: Anchorage Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Application for Annular Disposal of Drilling Waste in the Hansen # 1 Well Phillips Alaska Inc., by application dated January 7, 2002, has requested authorization to dispose of drilling waste through the annular space of the Hansen # I well in accordance with 20 AAC 25.080. Drilling waste may not be disposed in an interval that contains freshwater unless the commission finds that the freshwater has a total dissolved solids content of more than 3,000 mg/l, and is not reasonably expected to supply a public water system. The surface location of the Hansen #1 well is 2148' from the south line & 1527' from the east line, Section 2, T4S, R15W, Seward Meridian. The proposed interval for disposal of drilling wastes is at a depth of 3339' Total Vertical Depth, approximately 2100' offshore. Calculated salinity values from log measurements taken while drilling conservatively indicate a salinity of 6,000 parts per million at the surface casing shoe. A person may submit written comments regarding this request no later than 4:30 pm on February 7, 2002 to the Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on February 7, 2002 at 9:00 am at the Alaska Oil and Gas Conservation Commission at 333 West ih Avenue, Suite 100, Anchorage Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to February 1,2002. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before February 1,2002. C!~~L\¡)G:,}.~¡ Cammy ðechsli Taylor Chair Published January 17,2002 ADN AO# AO-02214019 NOTICE TO PUBLISHER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ~·~;£:·~;t~~~:~~U~~::~~r~~~~~~f~:·~:~~~~:~'~¡::ii:t: F AOGCC R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 sr A TE OF ALASKA ADVERTISING ORDER ") ) ADVERTISING ORDER NO. AO-02214019 AGENCY CONTACT DATE OF A.O. Jody Colombie PHONE January 16, 2002 PCN M ~ Anchorage Daily News POBox 149001 Anchorage, AK 99514 (907) 793 -1 ??1 DATES ADVERTISEMENT REQUIRED: January 17, 2002 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Type of Advertisement X Legal D Display Account #STOF0330 Advertisement to be published was e-mailed D Classified DOther (Specify) SEE ATTACHED PUBLIC HEARING ~ÊilQf.jÑt(QIºë~'ij:~~~΢~tl;:.: AOGCC, 333 W. 7th Ave., Suite 100 ~~~iki~i~:a';~~~~·~ì:~:~"";f¡;¡~1..i!¡;~lf1~f¡¡illftt~~~~~;'1W~ An h AK 9950 1 ,!ìill!l!@1}ßiWTl7JÆ!'¡¡L".cu. ,. .':if·I~U'st~'..'.s. ..,,,",.",.~:m'-'h< t:t. '. C orage, REF TYPE NUMBER AMOUNT DATE 1 VEN TOTAL OF PAGE 1 OF ALL PAGES$ 2 PAGES COMMENTS 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST lIO 01 02140100 73540 2 3 R~QUISITION~ E~Y: C'(Q[-.!· "t' . ¡ ~ 7 Ì\/\jl ~ G-- ( . l,-" DIVlfl?N APPROVAL: Uvb~h/}t ~i( 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER ) ') ADVERTISING ORDER NO. NOTICE TO PUBLISHER INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE AO-02214019 ¡::,:~¡'h~~?~~~~!i:I~~'~'~~?A~~~~~~: .. F AOGCC R 333 West 7th Avenue; Suite 100 o Plnchorage,AJC 99501 M AGENCY CONTACT DATE OF A.O. ~ Plnchorage Daily News POBox 149001 Plnchorage,AJC 99514 Joity Colombie Janu::try 16, ?.o07 PHO~E PCN (907) 793 -1 ??1 DATES ADVERTISEMENT REQUIRED: January 17, 2002 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: Account #STOF0330 United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2001, and thereafter for _ consecutive days, the last publication appearing on the _ day of . 2001, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2001, Notary public for state of My commission expires 02-901 (Rev. 3/94) Page 2 AO.FRM PUBLISHER NY PUBLIC LIBRARY DIV E, GRAND CENTRAL STATION POBOX 2221 NEW YORK, NY 10163-2221 US MIN MGMT SERV, CHIEF OCS STATS & INFO 381 ELDEN ST MS 4022 HERNDON, VA 20170-4817 TECHSYS CORP, BRANDY KERNS PO BOX 8485 GATHERSBURG, MD 20898 SD DEPT OF ENV & NA TRL RESOURCES, OIL & GAS PROGRAM 2050 W MAIN STE #1 RAPID CITY, SO 57702 LINDA HALL LIBRARY, SERIALS DEPT 5109 CHERRY ST KANSAS CITY, MO 64110-2498 XTO ENERGY, SUSAN LILLY 210 PARK AVE STE 2350 OKLAHOMA CITY, OK 73102-5605 OIL & GAS JOURNAL, LAURA BELL POBOX 1260 TULSA, OK 74101 DEGOL YER & MACNAUGHTON, MIDCONTINENT DIVISION ONE ENERGY SQ, STE 400 4925 GREENVILLE AVE DALLAS, TX 75206-4083 SHELL WESTERN E&P INC, G.S. NADY PO BOX 576 HOUSTON, TX 77001-0574 RAY TYSON 2016 MAIN #1415 HOUSTON, TX 77002-8844 ) OFFICE OF THE GOVERNOR, JOHN KATZ STE 518 444 N CAPITOL NW WASHINGTON, DC 20001 LIBRARY OF CONGRESS, STATE DOCUMENT SECTION EXCH & GIFT DIV 10 FIRST ST SE WASHINGTON, DC 20540 US GEOLOGICAL SURVEY, LIBRARY NATIONAL CTR MS 950 RESTON, VA 22092 AMOCO CORP 2002A, LIBRARY/INFO CTR POBOX 87703 CHICAGO, IL 60680-0703 ALFRED JAMES III 107 N MARKET STE 1000 WICHITA, KS 67202-1811 IOGCC, POBOX 53127 OKLAHOMA CITY, OK 73152-3127 BAPIRAJU 335 PINYON LN COPPELL, TX 75019 STANDARD AMERICAN OIL CO, AL GRIFFITH POBOX 370 GRANBURY, TX 76048 H J GRUY, ATTN: ROBERT RASOR 1200 SMITH STREET STE 3040 HOUSTON, TX 77002 CHEVRON, PAUL WALKER 1301 MCKINNEY RM 1750 HOUSTON, TX 77010 ) ARENT FOX KINTNER PLOTKIN KAHN, LIBRARY WASHINGTON SQ BLDG 1050 CONNECTICUT A V NW WASHINGTON, DC 20036-5339 U S DEPT OF ENERGY, PHYLLIS MARTIN MS EI823 1000 INDEPENDENCE SW WASHINGTON, DC 20585 DPC, DANIEL DONKEL 2121 NORTH BAYSHORE DR #616 MIAMI, FL 33137 ILLINOIS STATE GEOL SURV, LIBRARY 469 NATURAL RESOURCES BLDG 615 E PEABODY DR CHAMPAIGN,IL 61820 UNIV OF ARKANSAS, SERIALS DEPT UNIV LIBRARIES FAYETTEVILLE, AR 72701 RE MCMILLEN CONSULT GEOL 202 E 16TH ST OWASSO, OK 74055-4905 US DEPT OF ENERGY, ENERGY INFORMATION ADMINISTRATION MIR YOUSUFUDDIN 1999 BRYAN STREET STE 1110 DALLAS, TX 75201-6801 XTO ENERGY, MARY JONES 810 HOUSTON ST STE 2000 FORT WORTH, TX 76102-6298 PURVIN & GERTZ INC, LIBRARY 2150 TEXAS COMMERCE TWR 600 TRAVIS ST HOUSTON, TX 77002-2979 OIL & GAS JOURNAL, BOB WILLIAMS 1700 W LOOP SOUTH STE 1000 HOUSTON, TX 77027 AURORA GAS, G. SCOTT PFOFF 10333 RICHMOND AVENUE, STE 710 HOUSTON, TX 77042 MURPHY EXPLORATION & PRODUCTION CO., BOB SAWYER 550 WESTLAKE PARK BLVD STE 1000 HOUSTON, TX 77079 UNOCAL, REVENUE ACCOUNTING POBOX 4531 HOUSTON, TX 77210-4531 TEXACO EXPLORATION & PRODUCTION INC, CORRY WOOLlNGTON PO BOX 36366 HOUSTON, TX 77236 PHILLIPS PETROLEUM COMPANY, W ALLEN HUCKABAY PO BOX 1967 HOUSTON, TX 77251-1967 EXXONMOBIL PRODUCTION COMPANY, J W KIKER ROOM 2086 POBOX 2180 HOUSTON, TX 77252-2180 MARATHON, Ms. Norma L. Calvert POBOX 3128, Ste 3915 HOUSTON, TX 77253-3128 TESORO PETR CORP, LOIS DOWNS 300 CONCORD PLAZA DRIVE SAN ANTONIO, TX 78216-6999 BABCOCK & BROWN ENERGY, INC., 350 INTERLOCKEN BLVD STE 290 BROOMFIELD, CO 80021 GEORGE G VAUGHT JR POBOX 13557 DENVER, CO 80201 ') PETRAL CONSULTING CO, DANIEL L LIPPE 9800 RICHMOND STE 505 HOUSTON, TX 77042 MARK ALEXANDER 7502 ALCOMITA HOUSTON, TX 77083 EXXON EXPLOR CO, LAND/REGULATORY AFFAIRS RM 301 POBOX 4778 HOUSTON, TX 77210-4778 CHEVRON USA INC., ALASKA DIVISION ATTN: CORRY WOOLlNGTON POBOX 1635 HOUSTON, TX 77251 WORLD OIL, DONNA WILLIAMS POBOX 2608 HOUSTON, TX 77252 PENNZOIL E&P, WILL 0 MCCROCKLIN POBOX 2967 HOUSTON, TX 77252-2967 ACE PETROLEUM COMPANY, ANDREW C CLIFFORD PO BOX 79593 HOUSTON, TX 77279-9593 JIM WHITE 4614 BOHILL SAN ANTONIO, TX 78217 ROBERT G GRAVELY 7681 S KIT CARSON DR LITTLETON, CO 80122 EVERGREEN WELL SERVICE CO., JOHN TANIGAWA 1401 17TH ST STE 1200 DENVER, CO 80202 ) GAFFNEY, CLINE & ASSOC., INC., LIBRARY 1360 POST OAK BLVD., STE 2500 HOUSTON, TX 77056 MARATHON OIL CO, GEORGE ROTHSCHILD JR RM 2537 POBOX 4813 HOUSTON, TX 77210 EXXON EXPLORATION CO., T E ALFORD POBOX 4778 HOUSTON, TX 77210-4778 PETR INFO, DAVID PHILLIPS POBOX 1702 HOUSTON, TX 77251-1702 EXXONMOBIL PRODUCTION COMPANY, GARY M ROBERTS RM 3039 POBOX 2180 HOUSTON, TX 77252-2180 CHEVRON CHEM CO, LIBRARY & INFO CTR POBOX 2100 HOUSTON, TX 77252-9987 WATTY STRICKLAND 2803 SANCTUARY CV KA TY, TX 77450-8510 INTL OIL SCOUTS, MASON MAP SERV INC POBOX 338 AUSTIN, TX 78767 DIANE SUCHOMEL 105070 W MAPLEWOOD DR LITTLETON, CO 80127 US GEOLOGICAL SURVEY, LIBRARY BOX 25046 MS 914 DENVER, CO 80225-0046 C & R INDUSTRIES, INC." KURT SAL TSGA VER 7500 W MISSISSIPPI AVE STE C4 LAKEWOOD, CO 80226-4541 JERRY HODGDEN GEOL 408 18TH ST GOLDEN, CO 80401 RUBICON PETROLEUM, LLC, BRUCE I CLARDY SIX PINE ROAD COLORADO SPRINGS, CO 80906 JOHN A LEVORSEN 200 N 3RD ST #1202 BOISE, 10 83702 US GEOLOGICAL SURVEY, LIBRARY 2255 N GEMINI DR FLAGSTAFF, AZ 86001-1698 MUNGER OIL INFOR SERV INC, POBOX 45738 LOS ANGELES, CA 90045-0738 ANTONIO MADRID POBOX 94625 PASADENA, CA 91109 ORO NEGRO, INC., 9321 MELVIN AVE NORTHRIDGE, CA 91324-2410 SHIELDS LIBRARY, GOVT DOCS DEPT UNIV OF CALIF DAVIS, CA 95616 H L WANGENHEIM 5430 SAWMILL RD SP 11 PARADISE, CA 95969-5969 US EPA REGION 10, THOR CUTLER OW-137 1200 SIXTH AVE SEATTLE,VVA 98101 MARPLES BUSINESS NEWSLETTER, MICHAEL J PARKS 117 W MERCER ST STE 200 SEATTLE, WA 98119-3960 DEPT OF REVENUE, DAN DICKINSON, DIRECTOR 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 DEPT OF REVENUE, BEVERLY MARQUART 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 GUESS & RUDD, GEORGE LYLE 510 L ST, STE 700 ANCHORAGE, AK 99501 DUSTY RHODES 229 WHITNEY RD ANCHORAGE, AK 99501 FOREST OIL, JIM ARLINGTON 310 K STREET STE 700 ANCHORAGE, AK 99501 STATE PIPELINE OFFICE, LIBRARY KATE MUNSON 411 W 4TH AVE, STE 2 ANCHORAGE, AK 99501 AURORA GAS, J. EDWARD JONES 1029 W 3RD AVE, STE 220 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF AIR & WATER QUALITY TOM CHAPPLE 555 CORDOVA STREET ANCHORAGE, AK 99501 } NRG ASSOC, RICHARD NEHRING POBOX 1655 COLORADO SPRINGS, CO 80901- 1655 TAHOMA RESOURCES, GARY PLAYER 1671 WEST 546 S CEDER CITY, UT 84720 BABSON & SHEPPARD, JOHN F BERGQUIST POBOX 8279 VIKING STN LONG BEACH, CA 90808-0279 US GEOLOGICAL SURVEY, KEN BIRD 345 MIDDLEFIELD RD MS 999 MENLO PARK, CA 94025 ECONOMIC INSIGHT INC, SAM VAN V ACTOR PO BOX 683 PORTLAND, OR 97207 TRUSTEES FOR ALASKA, 1026 W. 4th Ave, Ste 201 ANCHORAGE, AK 99501 DEPT OF REVENUE, OIL & GAS AUDIT DENISE HAWES 550 W 7TH A V STE 570 ANCHORAGE, AK 99501 DEPT OF ENVIRON CONSERVATION, DIV OF ENVIRONMENTAL HEALTH JANICE ADAIR 555 CORDOVA STREET ANCHORAGE, AK 99501 DEPT OF REVENUE, CHUCK LOGSTON 550 W 7TH AVE, SUITE 500 ANCHORAGE, AK 99501 YUKON PACIFIC CORP, JOHN HORN VICE CHM 1049 W 5TH AV ANCHORAGE, AK 99501-1930 PRESTON GATES ELLIS LLP, LIBRARY 420 L ST STE 400 ANCHORAGE, AK 99501-1937 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS TIM RYHERD . 550 W 7th AVE STE 800 ANCHORAGE, AK 99501-3510 DEPT OF NATURAL RESOURCES, DIV OIL & GAS WILLIAM VAN DYKE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JIM STOUFFER 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BRISTOL ENVIR AND ENG SERVICE, MIKE TORPY 2000 W. INT'L AIRPORT RD #C-1 ANCHORAGE, AK 99502-1116 HDR ALASKA INC, MARK DALTON 2525 C ST STE 305 ANCHORAGE, AK 99503 ANADRILL-SCHLUMBERGER, 3940 ARCTIC BLVD #300 ANCHORAGE, AK 99503-5711 JAMES E EASON 8611 LEEPER CIRCLE ANCHORAGE, AK 99504-4209 AMERICA/CANADIAN STRATIGRPH CO, RON BROCKWAY 4800 KUPREANOF ANCHORAGE, AK 99507 US BLM AK DIST OFC, GEOLOGIST ARTHUR BANET 949 EAST 36TH AVE STE 308 ANCHORAGE, AK 99508 ') ALASKA DEPT OF LAW, ROBERT E MINTZ ASST ATTY GEN 1031 W 4TH AV STE 200 ANCHORAGE, AK 99501-1994 DEPT OF REVENUE, OIL & GAS AUDIT FRANK PARR 550 W 7TH AVE STE 570 ANCHORAGE, AK 99501-3540 DNR, DIV OF OIL & GAS JAMES B HAYNES NATURAL RESRCE MGR 550 W 7TH AVE, SU ITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, PUBLIC INFORMATION CTR 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 BAKER OIL TOOLS, ALASKA AREA MGR 4710 BUS PK BLVD STE 36 ANCHORAGE, AK 99503 ANADARKO, MARK HANLEY 3201 C STREET STE 603 ANCHORAGE, AK 99503 FINK ENVIRONMENTAL CONSULTING, INC., THOMAS FINK, PHD 6359 COLGATE DR. ANCHORAGE, AK 99504-3305 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC DICK FOLAND 6881 ABBOTT LOOP RD ANCHORAGE, AK 99507 US BUREAU OF LAND MNGMNT, ANCHORAGE DIST OFC PETER J DITTON 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 THOMAS R MARSHALL JR 1569 BIRCHWOOD ST ANCHORAGE, AK 99508 " GAFO, GREEN PEACE PAMELA MILLER 125 CHRISTENSEN DR. #2 ANCHORAGE, AK 99501-2101 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS JULIE HOULE 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 DEPT OF NATURAL RESOURCES, DIV OF OIL & GAS BRUCE WEBB 550 W 7TH AVE, SUITE 800 ANCHORAGE, AK 99501-3560 AK JOURNAL OF COMMERCE, OIL & INDUSTRY NEWS ROSE RAGSDALE 4220 B Street Ste #210 ANCHORAGE, AK 99501-3560 N-I TUBULARS INC, 3301 C Street Ste 209 ANCHORAGE, AK 99503 ALASKA OIL & GAS ASSOC, JUDY BRADY 121 W FIREWEED LN STE 207 ANCHORAGE, AK 99503-2035 ARLEN EHM GEOL CONSL TNT 2420 FOXHALL DR ANCHORAGE, AK 99504-3342 BUREAU OF LAND MANAGEMENT, GREG NOBLE 6881 ABBOTT LOOP ROAD ANCHORAGE, AK 99507 UOA/ ANCHORAGE, INST OF SOCIAL & ECON RESEARCH TERESA HULL 3211 PROVIDENCE DR ANCHORAGE, AK 99508 VECO ALASKA INC., CHUCK O'DONNELL 949 EAST 36TH AVENUE ANCHORAGE, AK 99508 TRADING BAY ENERGY CORP, PAUL CRAIG 5432 NORTHERN LIGHTS BLVD ANCHORAGE, AK 99508 US MIN MGMT SERV, RICHARD PRENTKI 949 E 36TH AV ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, RESOURCE EVAL JIM SCHERR 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4363 JOHN MILLER 3445 FORDHAM DR ANCHORAGE, AK 99508-4555 PHILLIPS ALASKA, LAND MANAGER JIM RUUD P.O. BOX 100360 ANCHORAGE, AK 99510 PHILLIPS ALASKA, MARK MAJOR A TO 1968 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, LAND DEPT JAMES WINEGARNER POBOX 10036 ANCHORAGE, AK 99510-0360 AL YESKA PIPELINE SERV CO, PERRY A MARKLEY 1835 S BRAGAW - MS 575 ANCHORAGE, AK 99512 DAVID W. JOHNSTON 320 MARINER DR. ANCHORAGE, AK 99515 GERALD GANOPOLE CONSULT GEOL 2536 ARLINGTON ANCHORAGE, AK 99517-1303 } US MIN MGMT SERV, AK OCS REGIONAL DIR 949 E 36TH AV RM 110 ANCHORAGE, AK 99508-4302 GORDON J. SEVERSON 3201 WESTMAR CIR ANCHORAGE, AK 99508-4336 US MIN MGMT SERV, FRANK MILLER 949 E 36TH A V STE 603 ANCHORAGE, AK 99508-4363 USGS - ALASKA SECTION, LIBRARY 4200 UNIVERSITY DR ANCHORAGE, AK 99508-4667 ANCHORAGE TIMES, BERT TARRANT POBOX 100040 ANCHORAGE, AK 99510-0040 PHILLIPS ALASKA, LEGAL DEPT MARK P WORCESTER POBOX 100360 ANCHORAGE, AK 99510-0360 PETROLEUM INFO CORP, KRISTEN NELSON POBOX 102278 ANCHORAGE, AK 99510-2278 AL YESKA PIPELINE SERV CO, LEGAL DEPT 1835 S BRAGAW ANCHORAGE, AK 99512-0099 JWL ENGINEERING, JEFF LIPSCOMB 9921 MAIN TREE DR. ANCHORAGE, AK 99516-6510 ARMAND SPIELMAN 651 HILANDER CIRCLE ANCHORAGE, AK 99518 / US MIN MGMT SERV, RESOURCE STUDIES AK OCS REGN KIRK W SHERWOOD 949 E 36TH A V RM 603 ANCHORAGE, AK 99508-4302 US MIN MGMT SERV, LIBRARY 949 E 36TH A V. RM 603 ANCHORAGE, AK 99508-4363 REGIONAL SUPRVISOR, FIELD OPERATNS, MMS ALASKA OCS REGION 949 E 36TH A V STE 308 ANCHORAGE, AK 99508-4363 CIRI, LAND DEPT POBOX 93330 ANCHORAGE, AK 99509-3330 PHILLIPS ALASKA, STEVE BENZLER ATO 1404 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, JOANN GRUBER ATO 712 POBOX 100360 ANCHORAGE, AK 99510-0360 PHILLIPS ALASKA, KUP CENTRAL WELLS ST TSTNG WELL ENG TECH NSK 69 POBOX 196105 ANCHORAGE, AK 99510-6105 ANCHORAGE DAILY NEWS, EDITORIAL PG EDTR MICHAEL CAREY POBOX 149001 ANCHORAGE, AK 99514 NORTHERN CONSULTING GROUP, ROBERT BRITCH, P.E. 2454 TELEQUANA DR. ANCHORAGE, AK 99517 ASRC, CONRAD BAGNE 301 ARCTIC SLOPE A V STE 300 ANCHORAGE, AK 99518 DAVID CUSATO 600 W 76TH A V #508 ANCHORAGE, AK 99518 TESORO ALASKA COMPANY, PO BOX 196272 ANCHORAGE, AK 99519 MARATHON OIL CO, OPERATIONS SUPT W.C. BARRON POBOX 196168 ANCHORAGE, AK 99519-6168 UNOCAL, KEVIN TABLER POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA), INC., MARK BERLINGER MB 8-1 PO BOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, SUE MILLER POBOX 196612 MIS LR2-3 ANCHORAGE, AK 99519-6612 o A PLATT & ASSOC, 9852 LITTLE DIOMEDE CIR EAGLE RIVER, AK 99577 DEPT OF NATURAL RESOURCES, DGGS JOHN REEDER POBOX 772805 EAGLE RIVER, AK 99577-2805 RON DOLCHOK PO BOX 83 KENAI, AK 99611 NANCY LORD PO BOX 558 HOMER, AK 99623 ) HALLIBURTON ENERGY SERV, MARK WEDMAN 6900 ARCTIC BLVD ANCHORAGE, AK 99518-2146 JACK 0 HAKKILA POBOX 190083 ANCHORAGE, AK 99519-0083 MARATHON OIL CO, LAND BROCK RIDDLE POBOX 196168 ANCHORAGE, AK 99519-6168 EXXONMOBIL PRODUCTION COMPANY, MARK P EVANS PO BOX 196601 ANCHORAGE, AK 99519-6601 BP EXPLORATION (ALASKA) INC, PETE ZSELECZKY LAND MGR POBOX 196612 ANCHORAGE, AK 99519-6612 AMSINALLEE CO INC, WILLIAM 0 VALLEE PRES PO BOX 243086 ANCHORAGE, AK 99524-3086 PINNACLE, STEVE TYLER 20231 REVERE CIRCLE EAGLE RIVER, AK 99577 COOK INLET KEEPER, BOB SHA VELSON PO BOX 3269 HOMER, AK 99603 DOCUMENT SERVICE CO, JOHN PARKER POBOX 1468 KENAI, AK 99611-1468 PENNY VADLA PO BOX 467 NINILCHIK, AK 99639 /. " OPST AD & ASSOC, ERIK A OPSTAD PROF GEOL POBOX 190754 ANCHORAGE, AK 99519 ENSTAR NATURAL GAS CO, PRESIDENT TONY IZZO POBOX 190288 ANCHORAGE, AK 99519-0288 UNOCAL, POBOX 196247 ANCHORAGE, AK 99519-6247 BP EXPLORATION (ALASKA) INC, INFO RESOURCE CTR MB 3-2 POBOX 196612 ANCHORAGE, AK 99519-6612 BP EXPLORATION (ALASKA) INC, MR. DAVIS, ESQ POBOX 196612 MB 13-5 ANCHORAGE, AK 99519-6612 L G POST O&G LAND MGMT CONSULT 10510 Constitution Circle EAGLE RIVER, AK 99577 JAMES RODERICK PO BOX 770471 EAGLE RIVER, AK 99577-0471 PHILLIPS PETROLEUM CO, ALASKA OPERATIONS MANAGER J W KONST P 0 DRAWER 66 KENAI, AK 99611 KENAI PENINSULA BOROUGH, ECONOMIC DEVEL DISTR STAN STEADMAN POBOX 3029 KENAI, AK 99611-3029 BELOWICH, MICHAEL A BELOWICH 1125 SNOW HILL AVE WASILLA, AK 99654-5751 JAMES GIBBS POBOX 1597 SOLDOTNA, AK 99669 AL YESKA PIPELINE SERVICE CO, VALDEZ CORP AFFAIRS SANDY MCCLINTOCK POBOX 300 MS/701 VALDEZ, AK 99686 NICK STEPOVICH 543 2ND AVE FAIRBANKS, AK 99701 RICK WAGNER POBOX 60868 FAIRBANKS, AK 99706 DEPT OF NATURAL RESOURCES, DIV OF LAND -REG MGR NORTHERN REGION 3700 AIRPORT WAY FAIRBANKS, AK 99709-4699 RICHARD FINEBERG POBOX 416 ESTER, AK 99725 SENATOR LOREN LEMAN STATE CAPITOL RM 113 JUNEAU, AK 99801-1182 ) PACE, SHEILA DICKSON POBOX 2018 SOLDOTNA, AK 99669 VALDEZ PIONEER, POBOX 367 VALDEZ, AK 99686 UNIV OF ALASKA FAIRBANKS, PETR DEVEL LAB DR V A KAMATH 427 DUCKERING FAIRBANKS, AK 99701 C BURGLlN POBOX 131 FAIRBANKS, AK 99707 K&K RECYCL INC, POBOX 58055 FAIRBANKS, AK 99711 UNIV OF ALASKA FBX, PETR DEVEL LAB SHIRISH PATIL 437 DICKERING FAIRBANKS, AK 99775 DEPT OF ENVIRON CONSERV SPAR, CHRIS PACE 410 WILLOUGHBY AV STE 105 JUNEAU, AK 99801-1795 l KENAI NATL WILDLIFE REFUGE, REFUGE MGR POBOX 2139 SOLDOTNA, AK 99669-2139 VALDEZ VANGUARD, EDITOR POBOX 98 VALDEZ, AK 99686-0098 COOK AND HAUGE BERG, JAMES DIERINGER, JR. 119 NORTH CUSHMAN, STE 300 FAIRBANKS, AK 99701 FAIRBANKS DAILY NEWS-MINER, KATE RIPLEY POBOX 70710 FAIRBANKS, AK 99707 ASRC, BILL THOMAS POBOX 129 BARROW, AK 99723 UNIVERSITY OF ALASKA FBKS, PETR DEVEL LAB DR AKANNI LAWAL POBOX 755880 FAIRBANKS, AK 99775-5880 Re: Advertisement Order ) ¡i J Subject: Re: Advertisement Order Date: 16 Jan 2002 12:35:10 -0900 From: Lorene Solivan <lsolivan@adn.com> To: Jody Colombie <jody_colombie@admin.state.ak.us> This ad is in, and is good to go for the dates you requested. Lorene 257-4296 On Wednesday, January 16, 2002, Jody Colombie <jody_colombie@admin.state.ak.us> wrot >Lorene please publish the attached hearing notice tomorrow. I will be >sending you another advertising order for an employment advertisement >later today. > >Thank you. > >Jody > > 1 of 1 1/16/02 12:47 PM 10f2 I I I Marathon Lact is a Federal Custody Transfer Meter and will have to be handled as follows. We will only be using the Marathon Lact for a gross bbl number due to proving logistics. The BS&W monitor will have to be blocked and sealed by Big G A new ticket will have to be installed by Big G for the Phillips Oil. 1/16/023:21 PM Location tanks will be gauged, water cut and water drawed if needed, re-gauged and loaded onto the trucks. Weaver Brothers will deliver the oil to the KPL Marathon Lact Unit and the trucks will offload. Oil will go into MGS line to KPL tankage. Haliburton is the 3rd party doing the flow test and the oil gauging in their tanks. Phillips will provide us with tank gauging documentation and all trucks will carry a bill of lading Jack Kralick stopped by today to discuss the movement of their oil and the following is what we discussed ---Original Message----- From: Samora, Paul Sent: Thursday, January 10, 2002 2:16 PM To: Brown, Shawn T.; Manzek, Rolf; Cason, Rodney S. Cc: Samora, Paul Subject: Phillips Oil Shawn Tom here is the proposed process for managing this oil. 'Brown, Shawn T. Tom Maunder, AOGCC II wrote PE By copy of this emaill am requesting that the responsible parties Phillips and Halliburton (Andy Bond or Jack Kralick) and Tesoro (Paul Samora or Shawn Brown) provide copies of the appropriate procedures for measurement at the weUsite and at the refinery. It would seem appropriate to determine the alternate plans possible at the refinery if BlM approval cannot be secured to use the Beaver Creek meter. I started to make a couple of calls today to see if there was a procedure in place for the various measurement activities (at the well site and Tesoro). It appears that there are plans in place, but the detailed procedures have not been finalized nor have the signed approvals of the various parties been secured. In particular the agreement and approval of the BlM to use the Beaver Creek meter has not been secured. In conversation with their Inspector, Bo Brown, they need to see the procedure documentation and give their approval. Their approval is not certain. I understand that the reason for proposing to use the Beaver Creek meter is to minimize any temporary rig up and the potential spill risk involved for getting the oil into the tanks. Gentlemen, First, thanks to Shawn for forwarding the note regarding the "arrangements" for accepting the potential production from the PPCo Hansen well. Subject: Re: FW: Phillips Oil Date: Wed, 16 Jan 2002 15:20:02 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Brown, Shawn T." <SBrown@tesoropetroleum.com> CC: "Samora, Paul" <PSamora@tesoropetroleum.com>, Andy Bond <abond@ppco.com> Jack Kralíck <jkrali@ppco.com>, Bill Lloyd <wlloyd@ppco.com>, louis R Grimaldi <Iou_grimaldi@admin.state.ak.us>, Lou Grimaldi2 <Igrimaldi@kenai. net> ;)~-;. Re: FW: Phillips Oil f - 'J '''"" ) \''C) , .. ~o ~T(:)~~ ) ~\.\-\ J~'\-\ ~~ ~OJ- 51 20f2 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission Paul Samora Tank Farm Supervisor Phone- 907- 776-3549 Cell-907 -398-1083 1/16/023:21 PM If this is ok with all or you see something different you would like let me know. will write up a procedure for the Tank Farm to follow during the offloading process. have talked with Tom Maunder (State of Alaska Oil and Gas) and he is aware of the process and his biggest concern is on the Phillips end on any oil recovered. have also talked with Don Irwin with Marathon about our plans and he is ok with it. Monday of next week to look at the offload process. The State of Alaska has agreed to take the documentation of between the meter and the gauges and he said Glenn with Weaver Brothers will be coming out on location tank gauges for the 0 discussed with Jack about discrepancies if any problems they would go with the gross count on the meters. Phillips is planning on a start date of 1-17-02. They have 2 zones they will be flow testing. They believe the zones will produce 3000 bbl's per day of crude oil. They will be cutting the crude with diesel. They are planning on a total of 12,000 bbl's but the number could be considerably less. They are expecting the length of the project to be about 4 days but all depends on how well the test goes. When Beaver Creek delivers Big G will have to change ticket and realign the BS&W monitor will be talking with Marathon to see if they can store up a few days so we don't have to change around quite so often. Re: FW: Phillips Oil ) WC7A- II c¡ 107- 1R1'tv1 \ I ~ 10:>- A#c V1~L- {)0s' G)j/o! o~. Re-enter suspended well _ Q. . Other X Time extension _ Stimulate _ ~ Request for Variance Perforate Annular Disposal 6. Datum elevation (OF or KB feet) CÎ' ~ R KB 1 63 feet ;::.-¡:::; 7. Unit or Property name ~ --- o \ jI"vt t; )(,,-2,/. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska Inc 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 21481 FSL & 1527' FEL, Sec 2, T4S, R15W, SM At top of productive interval 17501 FNL, 1641' FWL, Sec 33, T3S, R15W SM At effective depth At total depth 886' FNL, 551 FEL, Sec 32, T3S, R15W, SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural 93' 30" Conductor 698' 20" Surface 5177' 13-3/8" Intermediate 16,826' 9-5/8" Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service Exploration~ 8. Well number Hansen #1 9. Permit number / approval number 201-157 10. API number 50-231-20010-00 11. Field / Pool Exploration feet feet feet Junk (measured) feet Plugs (measured) Cemented Measured Depth 93' 698' 5,177' True vertical Depth 931 698' 3,3391 6,6951 RECEIVED JAN 0 7 2002 Alaska Ojl & Gas Cons. Comm' . Anchorage ISSIOO Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed p,?d- yy.¡~ Title: Drilling Team Leader Driven 803 sx 505 bbls 12.5 ppg 20 bbls 15.8 ppg 43 bbls 12.5 ppg lead 98 bbls 15.8 ppg tail 16,826' 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch X Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _ 14. Estimated date for commencing operation 15. Status of well classification as: January 7,2002 16. If proposal was verbally approved Oil Gas Suspended _ Questions? Call William Lloyd 265-6531 0/ I 107/0z- Date Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. I Plug integrity _ BOP Test _ Location clearance _ ~O~- e1)\o '. , Mechani~allnt..egrityTest_... SUbs.:q~ntform.re~uired10-~~M: 9~. (:a"~\o..~t)"\$.~~\ \'-\-J..""t "''''-'-.¡ ~\ '::",-,',>"\'..;,\.;.:(\\" <- èh.c...~s.n.\.\")Q~~\7'Id~Ç;. ~ ~\)Oa \.~ \) \~.. AJj:?n1 ~ 1Jngmal Sìgne t;y ~ / Approved by order of ,~he Commission Ca y Q tÞ I¡ C~m issioner _. _ Date / / / Ó;;..... \'l\u. "- ""..:> "" ð\ ""'\ICfo..<:\¡ \ \,W '">S"'::K'Z ~ \ ~.,,1't1~ ~::i\t'\C.r~ -\ C; "-- '<. (, ¡¿~ ð \ '-\.. ~ 'c. 'M. vJ Ji"'flj ~ Form 10-403 Rev 06/15/88. ¡ l.: ì \ ~ 1-\ L SUBMIT IN TRIPLICATE ) ) Cosmopolitan Project Hansen #1 Well 2209' FSL, 1546' FEL, See 2, T4S-R15W (Surface Location) KPB, Alaska REQUEST FOR ANNULAR DISPOSAL Phillips Alaska, Inc. hereby requests to dispose of drilling fluids associated with the drilling of the Hansen #1 well in the annulus between the 13-3/8" surface casing and the 9-5/8" intermediate casing. Details of this request are as follows: Current Casing Installation: 13-3/8" 72#/ft L-80 SL-BOSS set @ 5177' TMD, 3339' 1VD. Burst: 5380 psi, Collapse: 2670 psi Hole Angle @ Shoe: 73.3°, 1417' N, 2692'W of surface Cemented to Surface as follows: 1st Stage: 40 bbls CW 100 60 bbls MudPUSH 1st Stage: 425 bbls of Class G Lead @ 12.5 ppg 125 bbls Class G Tail @ 15.8 ppg (LWD Caliper run in this section indicated gauge wellbore. 1st Stage designed to cover from 5171' to Port Collar @ 990' MD. No excess required per AOGCC) Drop Plug and displace w/2 bbls cement, 10 bbls wash and 742 bbls of mud. Calculated displacement = 5416 strokes, bu~ped w/5279 strokes. Final displacement pressure = 642 psi, bumped to 850 psi. 2nd Stage: RIH w/TAM Combo tool, open Port Collar and establish circulation @ 6 bpm. Pump 20 bbls water, 125 bbls of Class G Lead @ 12.5 ppg followed by 20 bbls of Glass G Tail @15.8 ppgYisplaced w/21.7 bbls of water. Circulated approximately 45 bbls of cement to surface. Rotate Port Collar closed and pressure test same. 9-5/8" Intermediate Casing set @ 16826' TMD, 6695' 1VD 9-5/8" 47#/ft L-80 SL-Boss (16825' - 10034') Burst: 6870 psi, Collapse: 4750 psi 9-5/8" 53.5#/ft L-80 SL-Boss (10034' - Surface) Burst: 7930 psi, Collapse: 6620 psi Hole Angle @ Shoe: 70.7°, 6530' N, 12590' W of surface location Cemented as Follows: Single Stage: 40 bbls CW100 Spacer @ 8.4 ppg 60 bbls MudPUSH XLO @ 12.0 ppg 43 bbls 12.5 ppg Class G lead (15835' - 15332') 50% excess 98 bbls 15.8 ppg Class G tail (16825' - 15835') 50% excess Ran 2 tandem rise bowsprings on shoe joint, one spir~ider per joint on joints 2 - 7, 9, 11, 13, 15, 17, 19, 21. R~iprocated throughout job. Displace w/l082 bbls of mud - plug did not bump. Held pressure f/7 hours. 2) Wells within 1/4 mile of well accepting disposal (see attached) ') ) 3) Estimated volume to dispose of: It is anticipated that this well bore will be utilized to accept rain/snowmelt, drilling fluids, cuttings, and associated slurry fluids of approximately 75,000 bbls 4) Fluids to be disposed of will be water based drilling mud and wellbore cuttings (10 ppg base fluid used to drill surface wellbore), Invert emulsion oil based drilling fluids (10.0 ppg fluid used to drill intermediate wellbore interval) and associated cuttings and necessary diesel slurrifying fluid. Any collected rainwater and snowmelt will also be disposed of. 5) Maximum anticipated pressure at the outer casing shoe will be determined via freeze- protect operations and provided prior to approval of this request to inject. Estimated maximum rate will also be determined at this time. 6) Data supporting the shoe depth of the outer casing annulus is below any fresh water aquifers (see attached) 7) There are no hydrocarbon zones above the cement top of the inner casing string. (see attached mud log) 8) Disposal is anticipated to last 150 days due to the volumes and anticipated rate of injection. Unknown quantities of rainwater/snowmelt anticipated to buildup in the pits during spring rainy season may require additional time for injection. It is anticipated the total days of injection will likely not be concurrent. ,../' Phillips Alaska, Inc. recognizes the Commission may exercise its discretion to grant a 15 day public notice under provision 20 AAC 25.080 (e) (B) prior to granting full provision of this sundry request. As part of this sundry notice, Phillips requests an exception to the public comment period for the initial disposal of the following fluids from the fresh water pit: ,./ 1) Accumulated rain and snowmelt /' 2) Fluid portion of the fresh water drilling fluid used for the drilling of the surface wellbore, the source which is a privately owned fresh water gravel pit permitted with the Alaska DNR, Permit Number TWUP A2001-104. This fluid is from a surface source with a TDS less than that into which it will be disposed. v' The estimated volume of fluid associated with 1) and 2) is approximately 10,000 bbls. Due to the large amounts of recent snow and rainfall, it is requested to commence the disposal of this fresh water as soon as possible. No grind and disposal operations of the drilled solids in either the fresh water or oil based pits, nor will any disposal of liquid oil based drilling fluid take place until such time as any necessary public review is completed and AOGCC authorization is granted. ) .Mllm!'s ') ~l A Subsidiary of PH!LLlPS PETROLEUM COMPANY To: Robert Crandall, Bob Swenson Wayne Campaign Hansen #1 Shallow Salinities. November 9, 2001 From: Subject: Date: This memo will discuss the evaluation of the shallow portion of the Hansen well for the purpose of looking at the salinity of the sands near the bottom of the surface casing. We have acquired continuous porosity and resistivity data from measured depths of 3530' -5140'. I have evaluated this data for Volume Shale, total porosity (PHITT), and Apparent Water Resistivity (Rwa). Rwa was calculated from the total porosity and the resistivity curve, as stated in a previous memo. Included is a log presentation of the resistivity and porosity logs plus evaluation of V shale, a coal flag and Total Dissolved Solids calculation, highlighted in dark blue in the sands. Presented in the porosity track on the left, is the total porosity curve in red. This well is deviated 73° from vertical and there will be some problems with thin bed responses (see log, depths 4162' and 4170') where the TDS calculation will be in error. Another complication are interval of high carbonaceous, or organic content, often in the form of detrital coal. These can be picked out where the neutron and density porosities are quite high yet not enough to trigger the coal flag. Several are noted at the bottom of the log. .../ Inspection of the TDS curve in the thicker sa9ds indicate we are at 4500 ppm salinity at the top .... of the interval and increases to around 6000 ppm NaCI equivalent near the bottom. There are some potential sources of error in this evaluation and I will discuss those now. Included with this memo is an addendum on the ionic concentrations in these shallow meteoric waters. They are known to contain significant bicarbonate (HC03 -). This is a large ion with reduced activity. Presence of this ion will cause our calculations to Under-estimate actual TDS. Another source of error would be the resistivity measurement itself, in this highly deviated hole. Due to anisotropy, the tool will measure a value higher than the horizontal component we need for proper modeling. This error would also cause our calculation to under estimate the actual TDS. Due to this built-in bias, actual TDS values can be expected to be higher than the 6000+ ppm we show here. In conclusion, I expect the salinity to be greater than 6000 ppm in the logged section of this hole. If you have questions or comments, feel free to contact me. Wayne Campaign Sf. Staff Petrophysicist Phillips Alaska, Inc Philiips Alaska, inc, ¡s a SUbsídi,wy of Ph¡¡nps Petroleum Company ARCTIC GéJSCIENCE, we. ) 1000 O'MALLEY DRIVE, SUITE 205 · ANCHORAGE, ALASKA 99515-3069 January 4, 2002 Phillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Attention: Mr. Bill Lloyd Sr. Exploration Drilling Engineer Review of Regional Hydrogeologic Conditions COSMO Prospect, Hansen #1 Well Site Anchor Point, Alaska. Gentlemen: Arctic GeoScience Inc. (AGSI) has prepared this review of the regional geologic and hydrogeologic conditions at and proximal to Phillips Alaska Inc.'s (PAl) Hansen #1 Well, Cosmo Prospect located near Anchor Point, Alaska. We understand that PAl plans on disposing of drilling waste/waters by annular disposal at Hansen #1 well at or near the setting depth of the 13-3/8" surface casing which PAl has recorded at a depth of 5177 feet measured depth, 3339 feet TVD and is 3040 feet horizontally displaced from the surface location (1415 feet north and 2800 feet west of the surface location). AGSI has been requested to review regional hydrogeologic conditions to determine if the dispose drilling waste/waters could contact or affect local public water supplies. From AOGCC regulation provided by PAl (8) commission finds that the freshwater has a total dissolved solids content of more than 3,000 mg/I, and is not reasonably expected to supply a public water system; the commission will, in its discretion, provide 15 days notice and the opportunity for a public hearing in accordance with 20 MC 25.540 before making that finding; 1.0 Regional Geologic and Hydrogeologic Conditions The following section presents our review of publicly available data, and the available site-specific data regarding the hydrogeologic conditions present at the Cosmo Prospect. 1.1 Physical Setting The Seldovia SW (0-5), Alaska (USGS, 1987) 1 :25,000 scale topographic map is used for notation of surficial features and provides the base map for Figure 1. The drill pad is \ F;t~, ' ~\Jìr" -. -.~~. ~~.' . /.# ~ ....--\(~' Phone {9071 522-4300 FAX {9071 522-4301 ) ) 01-0594 Page 2 located at a surveyed elevation, provided by a PAl contractor of 145 feet above mean sea level, on top of a bluff adjacent to the Cook Inlet. The terrain is generally a flat rolling surface with limited surficial features. Due to Stariski Creek located to the east and north, the area can be described as a terrace. The bluff to the west drops approximately 150 feet to the mean high water level of the Cook Inlet approximately 500-feet west of the drilling operations area. Stariski Creek is incised in the terrace and bluff to the north and east of the property (nearest distance - 1500 feet from drill pad) at an approximate elevation 120-feet below the property. To the south of the operations area, the terrain remains at a similar elevation as the Phillips drill pad and consists of rolling terrain. 1.2 Regional Geology The Cook Inlet is a narrow, elongate trough of Mesozic, Tertiary, and Quaternary sediments. The basin of deposition covers approximately 14,000 square miles, and is bounded by the Kenai, and Chugach Mountains on the east, the Talkeetna Mountains and the Copper River basin on the Northeast, the Susitna Basin on the north, the Chignit Mountains and the Alaska Range on the west, and Shelikof Straight on the South. The geologic history of the Cook Inlet basin is highly complex and reflects a history of repeated geosynclinal sedimentation, deformation, and intrusion beginning late in the Paleozoic and extending to the present. The maximum thickness of the post-Paleozoic sediments deposited in the deepest part of the basin is estimated to be 40,000 feet. The total reconstructed volume of these sediments is estimated to be greater than 80,000 cubic miles (Kelly, 1963). Three Mesozoic cycles of sedimentation and two Tertiary cycles have been recognized (each bounded by a period of orogeny). Rocks of the Mesozoic age consist of limestones, cherts, volcanics, and a variety of clastics deposited in a variety of marine environments. Tertiary sediments consist of conglomerates, sandstone, siltstone, claystone, and coal. The late Tertiary is known as the Kenai Group. The Kenai Group \. .!~- __ I _.- ) ) 01-0594 Page 3 has been broken down into five supporting formations by Calderwook and Fackler (1972). The Kenai Group contains all the current oil and gas production in the basin. Calderwood and Fackler (1972) formally proposed the formation names, which in ascending order are presented as the West Foreland Formation, the Hemlock Conglomerate, the Tyonek Formation, the Beluga Formation, and the Sterling Formation. A discussion of the Tyonek Group is presented below. The West Forelands and Hemlock Formation are below the area of interest to this study. The Tyonek Formation consists of massively bedded sandstones and thick coal beds interbedded with siltstones and claystones. The thickness in the type section is observed from production and exploration well logs to range from 2,000 feet to 7,000 feet (Hartman 1972). The coal beds are far more pronounced in this formation than in any other Kenai Group unit. The Beluga Formation at UNOCAL Beluga River No. 1 (212-35) is 4150 feet thick and consists of thin interclated beds of claystone, sandstone, siltstone, and lignite to subbitumious coal. The Beluga Formation is thickest in the area of the Tyonek and Beluga Rivers, at approximately 6,000 feet thick, and thins in the area of Swanson River Field, (Hartman 1972). The outcropping Beluga Formation on the east side of Cook Inlet was deposited on alluvial fans and plains by short, high-gradient, braided streams which carried sediment southwestward from the Kenai-Chugach Mountains. The Sterling Formation consists of a sequence of massive sandstones with interbedded claystones and thin coals. The type section from well and seismic data indicate the thickness of the Sterling Formation and Quaternary sediments ranging from 4,000 to 10,000 feet in the East Forelands area, (Hartman 1972). The formation thins southward and is overlain unconformably by unconsolidated Pleistocene and Recent (Holocene) sediments. In contrast to the Beluga Formation, the Sterling Formation represents deposits of considerably larger meandering streams and rivers that transported sediment south to southeastward from the Aleutian-Alaska Range. The Pleistocene sediments are predominately of glacial origin and overlay the Kenai Group sediments of Teritary Age. Upper Cook Inlet underwent extensive glaciation during the Pleistocene epoch. The most recent advance (the Naptowne) occurred \. \1<_ __ I _..- \[ .,) } 01-0594 Page 4 14,000 years ago (Karlstrom 1965). The Naptowne was proceded by the Knik, Eklutna, and Caribou Hills glacial advances. The Hansen #1 drilling operations is located within the Kenai Lowlands physiographic province consisting of Quaternary age surficial deposits, underlain by Tertiary age deposits of the Sterling and Beluga Formations. The geologic map of the Seldovia Quadrangle, South-central Alaska (Bradley, et. aI., 1999) indicates an outcropping of the Beluga Formation to the southwest of the property. 1.3 Regional Hydrogeology The surficial deposits in the area reportedly yield effective water sources for use as potable water for area residents. Residential wells are reported at depths ranging from 20 to 40 feet below grade with depth to water ranging from 20 to 30 feet below grade. These aquifer deposits are likely associated with either the Alluvial Channel Aquifer or the Moraine Aquifer as described by Regar and Petrik, (1993). The Alluvial Channel Aquifer is described as elongate channel fillings consisting of well-sorted pebble, gravel and sand deposits with few to numerous boulders in former drainage channels. The sequence generally exhibits fining upward. Reported yields are 5 to 15 gallons per minute. The depth to the bottom of the aquifer is reported up to 37 feet below grade. The Moraine Aquifer is described as heterogeneously mixed sand and pebble- cobble gravel, with silt and clay till, deposited by a southward flowing glacier in Cook Inlet. The till and glaciolacustrine deposits may be locally channeled and terraced. Locally the aquifer is overlain by loess, clay-silt based topsoil, or peat. Reported yields are 0 to 50 gallons per minute. The depth to the bottom of the aquifer is reported up to 120 feet below grade. The Bedrock Aquifer is also known as the Beluga Formation of the Kenai Group of Tertiary age. This aquifer consists of moderately to weakly indurated fine- to medium-grained sandstone interbedded with siltstone, shale, claystone, and thin layers of bony coal (Adkison and others, 1975). This aquifer underlies all surficial deposits in the project area and is the oldest aquifer unit. Water is generally , obtained from saturated sandstone and coal layers in the aquifer. Depths to } !" - ., ".. ,:::,- _... I. ~___ ) ) 01-0594 Page 5 bedrock in the region vary. There are a total of 16 wells in the Anchor Point area that utilize the bedrock aquifer. Three of these wells are dry, two are test holes, and one is an observation well. The deepest water well reported in the Anchor Point area was drilled in this aquifer (SC5-15-4ABDC2-27) approximately 5 to 7 miles from Hansen well location. It is 380ft (115.9m) bls and obtained water from 140 to 143 ft (42.7 and 43.6 m) bls. The remainder of the hole was reported non- water producing and used for storage. The soil boring logs prepared from the groundwater monitoring wells, the conductor pilot hole, and the drillsite water well identify the local aquifer deposits of sand and gravel to be near surface (25ft) overlying a layer of claystone/siltstone. This layer of low permeability claystone/siltstone may be a confining layer to water flow and therefore may act as a controlling surface to water flow through the aquifer (e.g., channeling or accumulation of water). Several springs were observed along the bluff to the west and southwest of the site, discharging from unconsolidated sand, gravel and silt overlying a layer of siltstone/claystone with interbedded sand at approximately 20 to 25 feet below the top of the bluff (AGSI field observations). This evidence suggests the layer of siltstone/claystone acts as a confining layer to downward water flow and the overlying deposits of sand and gravel provide the aquifer for this source of water. Using the water levels encountered in the monitoring wells of 14.5 to 19 feet below the ground level surface and the elevation of the observed springs below the top of the bluff (20 to 25 feet), the potentiometric surface (i.e., water table) is generally dipping to the west from the drilling operations area to the bluff. As noted above, the confining surface of the claystone/siltstone layer may also create local effects on the water table surface and the water flow (channels or accumulations). The local aquifer at the wellsite is probably a perched aquifier. A perched aquifer occurs when a layer of low-permeability material, found as a lens in more permeable material, intercepts water moving downward through the unsaturated zone. The water accumulates on top of the lens producing a layer of saturated soil above the main water } !I . ., c. .'.::J_ __ 1._'- ) ) 01-0594 Page 6 table. The water may move laterally above the low-permeability layer up to the edge and then sweep downward toward the main water table or form a spring. Perched aquifers are common in glacial outwash, where lenses of clay formed in glacial ponds or lakes are present (Fetter, 1980). A groundwater study was performed in 1993 for the Anchor Point area entitled, "Aquifers and Hydrology at Anchor Point, Alaska" by W. A. Peck of the Alaska Department of Natural Resources, Division of Water, Alaska Hydrologic Survey. The report presents a compilation and summary of groundwater conditions from wells in the area. Summary of their findings was based on twenty-six public-water supply well locations. This includes 2 class A wells, 10 class B wells, and 14 class C wells. All public-water supply wells have ADEC PWSI numbers except 11 class C Wells. As a result of their studies the major potential limitation to the bedrock aquifer's utilization is saltwater. Oil and gas exploratory data (McGee, 1977) suggest a freshwater/saltwater interface ranging from approximately 100 to 320 feet (ft) (30.5 to 97.6 m) bls from the western to southeastern edge of the project are, respectively. The gradient of this interface is approximately 33 ft per mile (6.3 m/km). These data are not supported by reported water-well data. The deepest water-bearing strata reported in the AK DNR study was 244 ft (74.4 m) bls in a 360 ft (109.8 m) hole (SC5-15-04AACC). They reported that no indication of saltwater was indicated on this well log despite other complaints of coal-related water quality problems noted. This well is located in an area where McGee estimated the freshwater/saltwater interface to be approximately 140 ft (43.0 m) bls. Discrepancies may be due to the difference in the scale of this (1 :25,000) and McGee's study (1 :500,000) and topographic variation. A conductivity borehole log from Standard Oil Company of California's oil and gas exploratory Anchor Point NO.1 well (SC5-15- 1 OCCAC2-1), approximately 1.25 miles (2 km) east of the inlet at an approximate elevation of 215 ft (66 m), suggests brackish water encountered approximately 210ft (64.1 m bls and turning to saltwater by 275 ft (83.9 m) bls. Owners of a 213 ft (65 m) well drilled adjacent to the Cook Inlet bluff, just north of the mouth of the Anchor River (SC4-15-33DDCC1-4), indicated no saltwater problems, although domestic use was discontinued due to coal-associated water quality problems. Based on these observations, the saltwater/freshwater interface exists, although the gradient calculated from McGee's data is less within the project area. ,\ Ä .:} . i. \A".J_. _.. I ...- ) ) 01-0594 Page 7 2.0 Summary of Findings In summary of our literature review of regional hydrogeologic conditions the probability is very low to none that the drilling waste/waters disposed in the bedrock of the Tyonek Formation could contact or effect local public water supplies in the Anchor Point area. This interpretation is based on two major limitations; 1) the volcaniclastic tuff within this strata which acts as an excellent vertical permeability barrier that can have great lateral continuity, and 2) the relatively shallow depth of the saltwater interface. The 13 3/8 inch casing shoe is set in the Middle Tyonek Formation, which underlies both the Sterling and Beluga Formation under much of the basin. It is composed of an interbedded series of sandstone, siltstone, mudstone and coal, all deposited in a fluvial, non-marine setting. Volcaniclastic tuff is a ubiquitous lithology within this strata and is associated with the near constant (in geologic time) eruption of volcanos to the northwest in the arc sequence. This interbedded tuff, as well as reworked tuff in the fluvial strata, acts as an excellent vertical permeability barrier that can have great lateral continuity (i.e., large eruptions tend to blanket an entire area and become part of the rock record). This can be evidenced in the numerous independent gas accumulations in the Tyonek Formation within the fields. The middle to lower Tyonek formation often contains vertically separated gas reservoirs which proves the sealing capacity of tuffs and mudstones (e.g., gas normally has a much higher mobility than water). The potential for conductivity or transmissivity of the disposed drilling waters from the Tyonek Formation through the Beluga and Sterling Units to the local surface groundwater supply wells has a very low probability to not likely. The salt-water contact is at a depth mapped in the region ranging from 100 to 200 -ft. bls. This depth limits potential bedrock freshwater aquifers, and restricts the available groundwater available for public use to the near surface Alluvial Channel Aquifer and Moraine Aquifer. Water quality in bedrock aquifers above the salt-water interface has been associated with poor water quality in the coal water-bearing zones and subsequently has limited utilization of the bedrock aquifer for domestic use in the vicintity of Anchor Point. ,~ 1',_ _... I .....- ') ) 01-0594 Page 8 3.0 Closure Arctic GeoScience Inc. appreciates this opportunity to support Phillips Alaska Inc. with your Hansen #1 well, and continues to remain available. Should you require any additional information or have any questions please do not hesitate to contact Mr. Chris Nettels, GeoScience Group Manager or the undersigned. Sincerely, Arctic GeoScience Inc. ~~ Michael G. Schlegel Technical Consultant President/CEO \ j¿ . ., c.. . . /: ,_. __ I _.- ~.; - I L CJ " ~ <4: I I ~ -'; "" " 11. ~ I Fig 3. Site Features Cosmo Project Anchor Point Kenai Peninsula, Alaska Legend + ~~, .Jtc } '~" §f: ~::,; .~~-::: &,..~, - ·':;f~~;:;f.>' ..,~~~",~~ ~,~'" , -. ~:~ ~":. Spring LJ Sediment Sample 1:.] Surface Water Sample [)ì Surface Water/Sediment Sample ~ Proposed Potable Water Well '" Monitoring Well 1> Well Head Water Supply Well Nates: · SW/SD-04 (Mouth Of Storiski Creek) Point Not Shown · Aerial Photograph Bose Supplied By Phillips Alaska WGS t984 UTI.! Zone 5 North Transverse Mercator Falss EasUng: 5??oo0.o00ooo Falss Northing: 0.000000 Central Meridian: -153.o00ooo Scale Factor. .999600 Latitude Of Origin: 0.000000 Drawing f"rtle: Site Features Map Phase II Enviromental Assessment Cosmo, Prospect, Hansen #1 Exploration Well Site Phillips Alaska, Inc. Designed By: Date: Project No: CN SEPT 2001 01-0594 Drawn By: File Name: PAR FIG3 Fig No: Checked: Seale: 3 CN NTS Projed: Client: ~ Re: Hansen #1 Update - Request for Extension ') Subject: Re: Hansen #1 Update · Request for Extension Date: Tue, 11 Dec 2001 12:56:24 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: William B Lloyd <wlloyd@ppco.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Winton GAubert <winton_aubert@admin.state.ak.us> Bill, Given the information you have provided, your request is appropriate. Please plan to test the stack when you next get to the bank. Are there likely to be any DP logs?? To help reduce your "book" test time, you might take advantage of the opportunity to test the choke manifold and other surface equipment while drilling operations are ongoing. Good luck with the well, please keep us informed as to operational progress. Tom Maunder, PE AOGCC William B Lloyd wrote: > Mr. Maunder, > > We are currently drilling in our 12-1/4" intermediate interval at -14,250' > MD with an estimated TD of -16,900' MD. Our ourrent daily Rap is -450,/day > therefore I antioipate TD'ing this interval on Monday, 12/17. At that > point we will trip to run 9-5/8" casing. > > Our last BOP test was on 12/4 and our next is soheduled for today. As with > our last test, I am requesting to delay the required BOP test until our > next TOOH, either at TD or as bit/BHA/hole conditions may warrant. > > Please let me know if this request is acceptable. I apologize for the late > notice on this request. Thanks > > Bill Lloyd > Sr. Exploration Drilling Engineer > Phillips Alaska, Inc > 700 G Street A TO-1568 > Anchorage AK 99510 > 907.265.6531 (office) > 907.244.5616 (cell) > 907.265. 1336 (fax) Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 10f2 ) ~O\-\S~ 12/11/01 12:56 PM Update ) ) Subject: Update Date: Mon, 26 Nov 2001 11 :44:59 -0900 From: "William B Lloyd" <wlloyd@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> JO\ - \5, Tom, Just to give you an update on the operations on Hansen: We ended up fishing a bull nose from the 3rd PDC hole opener...it looked like a fatigue break in the throat area behind the blades. We ran all the way to TD without seeing a thing with the poor-boy overshot, set down and rotated and came out of the hole with the fish. Worked great, hole was exceptional. We immediately turned around and ran our 13-3/8" to TD with 2 tandem rise centralizers at the shoe, 9 spiragliders and 2 bowsprings around the port collar at -990'. We did our first stage and put red dye in the wash ahead, then opened the port collar and did our second stage. We saw the dye ahead of the cement indicating our first stage was right where we wanted it. We also detected some cement as well (phenolphthalien). This was the first run of a 13-3/8" port collar and the first run of a left-hand rotate to open port collar in AK and it worked great - it's a fool proof tool. After the cement job we went into the standard, ND/NU and test that also went very well. We ran in and displaced our WB mud to invert, PU 15,000' of pipe then drilled out and did our FIT to 13 ppg. Came out and PU the 12-1/4" PDC and Autotrack and are currently drilling ahead. Things are going great. A good lesson on this well. Here we are at 73 degrees in a 17-1/2" hole that we went in and out of numerous times. There were at least 5 Inlet-wise folks that told me it was the best shape hole they'd ever seen in the inlet. I think that speaks volumes of testimony for big jets, high flowrates, good solids control, lots of rotation while drilling. Bill Lloyd Sr. Exploration Drilling Engineer Phillips Alaska, Inc 700 G Street A TO-1568 Anchorage AK 99510 907.265.6531 (office) 907.244.5616 (cell) 907.265.1336 (fax) 1 of 1 11/26/011:12 PM CASING TEST and FORMATION INTEGRITY TEST Well Name: Hansen #1 Date: 11/23/2001 Supervisor: Lutrick/Whitlock CASING TEST DATA LEAK-OFF DATA o Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight MINUTES MINUTES roR roR LOT STROKES PRESSURE eSG TEST STROKES PRESSURE i~~~~~~~~~~~~~~~~¡~~~~~~!~~~~~¡~~~~~Q~P-~~~~~~~¡ ~~~~~~~~~~~~~~~~~~~~~Q~~~~~~~~¡~~~~!~~i~~~~~~ : : 2 stks : 50 pSI : : : 4 stks : 349 pSI : [~~~~~~~~~~~~~I~~~~~~!~~~~I~~~Ü~~j?~!~)j"G~~~~~~~~~~~~~I~~~~~~~~~~J~~~~~~~p-~~~~] L--------------L--~--~!~~---L--~º~.P~!~n ,_______________L_!~_~~_~~__L--?~~-P..~~n-j i----------------L--~-~!~~---L-~~~.P~!-~,~--------------L-!~_~!~~__1_---~!~-P..~L--j i----------------L--~-~-~!~~--¡---~!!~-I?-~!-~~~------------__~--~º-~!~~--~---~!~~ZJ~~i--~ L.--------------¡--~~-~!~~--J---~~~.P~!-) ~þ-------------_~--~~-~!~~--~--!!~~-~J~~~-~ L--------------¡--~-~-~!~~--i---~!!~.P~!-~ ~-------------~--~~-~!~~--~--!!~?~J~~i--~ L______________L_~_~_~!~~__L__~~~.P_~!___J L________________L__~~_~~_~~__L!!~~~_E~~J ! ! ¡ ¡ ! ! 36 stks ! 1,840 psi ¡ :----------- ----- T -- ----- ----.. --- t- -------............... --1 ~--_.......... --................ ~.. -- ----- --........... -1-- --... --- -- --..... -;--1 : : : : : : 40 stks : 2,068 pSI : 1----.. ____ _.._____....._.... ____ __ ---.. --.. -------............... --..... of 5- --............. --.................. ~-_.... --.......... -- -- -..--....... --- ---....... ---... ¡ ¡ ¡ ! ! ! 44 stks ! 2,240 psi ! [~~~~~~~~~~~~~I~~~~~~~~~~~~~~I~~~~~~~~~~~~~~J [~~~~~~~~~~~~~~I~~~~~I~~~I~~~~~~~ë~~~] ! ! ¡ ¡ ¡ ¡ 52 stks ! 2,655 pSI ¡ ¡~~~~~~~~~~~~~~~I~~~~~~~~~~~~~~~!~~~~~~~~~~~~~~~~~] [~~~~~~~~~~~~~~I~~~~~I~~]~~~~~~~~~ë~~~] : : : : : : 58 stks : 3,009 pSI : :-------------- --+-- - ------------ t- ---- ---- -- -- -- -- i ~----------- - - -- - ~ - n -------- - - - - i ---- - - ---- --- - ----I I I I I I I I I I I I I I I I I :--------- --- -- --+...... ------.... ---- t- ---- ---.............. --1 ~---...-..- ----...... -- ~_.... --...... ---.. -- -1--- -- ---.... ---..........-: I I I I I I I I I I I I I I , I :----------------T---------- -.. ---~ ---- ----.... -- --- --1 ~--_............ -- -- -- -t-- -- --..- -- -----1- -- ---- -... --- --""-1 I I I I I I I I I I I I I I I I 1______ __________.....____ -----------.- -- -- -------- ...-.. --.. f- -- ---- -- ------ -- ~-......... -- ----.......... of ----....... ------- ---.. I I I I I I I I I I I I I I I I I I I I I I I I 1--------- -------..... ----------... ---- +--------............ --.. -- '" I I I I I I I I I I I I 1----------------.,----------... -- ---,.-- -- -- ----.......... ---~ I I I I I I I I I I I I 1---------- ------,..------ -- -------T-- ---....... -- -- -- ---., I I I I I I I I ¡---------------- ! : ; ¡ : ! ! : SHUT IN TIME : SHUT IN PRESSURE i~~~Q~9-~~r~~~r~~~~~~;O~¡~~$~º~~~!~~~~ : 1 .0 mln : : 460 pSI : r--2~õ-ñilñ-I-------"t:\"(j--~-42ö-psr--l 1----------------..... -- - ------ -- --... -1C;'------ -- -- --......., ! 3.0 min! ~s: 395 psi ! 1--- -------------"T"'---------- -- ---"(:------ --...... -- --, ! 4.0 min! ab! 375 psi ¡ ¡---5~õ-ñilñ---r--------;¡\)-t<-355-p-šï---1 i---6~Õ-ñilñ---t---------r~-t~34Ö-psï---1 ¡---7~õ-ñilñ--t---------\~--~325-pSr--1 .------- ------ ---.....-- -- - -------,.-~ ~- ---- ---------_.! ! 8.0 min! I~ ¡....310 psi ! r--9~õ-ñilñ---r--------lÇF-295-psr--l [~iQ~~~~~[~~[~~~~~~~~~~~~~~~~j?~~!~] Casing Size and Description: 13-3/8" 72# L-80 SL-Boss Casing Setting Depth: 5,17T TMD Hole Depth: 5,2111 TMD 3,3391 TVD 3,349' TVD /- Mud Weight: 9.9 ppg Length of Open Hole Section: 341 EMW= Leak-off Press. + Mud Weight = 540 psi + 9.9 ppg 0.052 x TVD 0.052 x 3,349' EMW for open hole section = 13.0 ppg Pump output = 0.1400 bps Fluid Pumped = 2.2 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi . 28CoOps; _c_ ?700p-:'1 - 2.f,('lI pi! - '2.~,(tOp51 - 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psi a: 1,800 psi ;:) 1,700 psi en 1,600 psi ffi 1,500 psi a: 1,400 psi Q. 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi . 700 psi I ;: E~~¡ 01'. i..' :.', 300ps~ Ii: 200 ps~ - ¡ I ! 100 ps~ Þ i ! : i OPSI_~~~¿~~~~~~~~~~~*~~~~~ : 1 ¡III! IIIIIII! I II III I III! III!!HI 1I111H11II¡1!lj¡~ I lHtl?: !HI¡J IIIIHt1lltHl' .: . ,!, I 'II "''''-'foL~.<t<L'iò<j,,.~-;:i'"'-l!'''-'"' , 1 I I r r! I I ~ f I I I 1 I J I : I I I f I I I r I' I I 1__ _ I_~~.:.!"::::"~ _ _ ! -- I 'ITIME LINE : I , I I, " , , -- -,--- I ,-:- 1- I I ONE MINUTE TICKS - :. I, , II I I I , I I I -e- LEAK-OFF TEST ~CASING TEST ~~i>~ LOT SHUT IN TIME --:i:- CASING TEST SHUT IN TIME -+- TIME LINE ------- i ' ~ ¡- ! ! SHUT IN TIME ! SHUT IN PRESSURE r---õ-.ö-m-iñ---r--------------T--3~õö9-psf-l .. --- -- - - - - ---- -- -.. ---- - - -- -- - - - -- ~--- --- --- --- ---.--, : 1.0 min : : 3,009 pSI : ~- - -- -- -- ---.- __n ~ - -- - - - - - --- -- - - i - ----- - ------ - -~ - ~ : 2.0 mln : : 3,009 pSI : :. - - -- -------.- -- - - ~ - -- -------- -- - - i ---- -- ---------.---1 : 3.0 mln : ; 3,000 pSI : ~------- ----................ ~... -- -- -- ----......... -1----... --------... -;-- i : 4.0 mln : : 3,000 pSI I f~~~~~~~~~~~~l~~~~~~~~~~~~~l~~~g~~~~~~F1 r---=ï.ö-m-iñ---r---------------1--2~99-š-psrl r---š~ö-m-iñ--T--------------1--2~99Š-psf-l r---9-.Ö-m-iñ---r---------------r-2~99Ö-psf-l :--- -- - - - -- -- -:- -- - ~ ------ -- -- - - ---i--- - - ----------.--~ : 10.0 mln : : 2,990 pSI : :--- -- - - - - ----:--- - ~ ---- -- -- - - -- -- --1--- ----- -------.---1 : 15.0 mln : : 2,990 pSI : ~ -- --......... -- -- --;- --... ~ ---- -- --...... -- ---1- -- --... -- ---- ---.---1 : 20.0 mln : : 2,990 pSI : ~----- --............ -:............ ~ ---- -- -- --...... -- -1-------- -----... -;--1 : 25.0 mln : : 2,990 pSI : [~~~g~Q~~J~~~[~~~~~~~~~~~~~~~[~~~~~j~~(] f~"'" - - ------ ------.- --- ~--- --- _._-- w w ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ - ~ - ~ - - - - - - ~ ~ 0 0 0 - - ro NNW ~ ~ ~ ~ ~ ~ m m m ~ ~ 00 ø - m w w ~ - ~ w w ~ - m w w ~ - m w w ~ - m STROKES NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above SChlumberler Well Fiéld Efluh..,er Country Time 14;31;35 14:49:2.1 15:0':0' 15:2-4:$3 15:42:39 16~OO:25 Hansen 1 tt: Richard Koziel United States \ ì 1 Cement Job Report Phlllip$ CHeRt $IR NØ. Job Type 13-3/9 SUrf ~~CÐ Jtlb Dillie 11-19-2001 -.------.-......-...--....... ...--...-.... Þré$$\lrê ---- ...... -.. ,_..-..,, ..... -........ .."'¡O-----.--..----.. ....... . Density .. . ..., .... Q~tè -..------.........-,-.--- .--.- ----.-..-.- .. L. i 1 \ . I - I t I j ¡ I I I i .16:18:11 ' t 16;35: 5" ~ 1&;53;43 17;11:29, r i I ._J__ ))n:mm:~ 10:1I Æ1 *'0 ØJS 'III_'~.= - PS1 \\ O~ \ '::::;. ~ J ~ .+-.- ¡ .... .. ..1 .,... i ~I ~r~ ~ ~ I ... .~..~ r-" í I --- 1 ..' . ....·....r.. -._,_,.1 I I I. I ! .-- ._,,-- 4Hr IoJj g \ '9 1.1 J"~ ... 1.7 LJ JA.O I . , I ! i ~ u u BlH ... ... t.8IG 11"_ _. ....__-' _....._ 0... _00" .... . J'. _. "'I ·__....·\1·01_ ..." ¡ ¡ ! I I I II U, CèmCAT v1.0 ....... .... -..------ ----.... ..... 0'.._ ~' ...-... _·..··...0 ..__ MeS5lllges -'"" '\..-.._- --..- . -.'. Wa~r Ahet!d PreJ.s\nc 'test Lines Relet Volutnt! Re!iet Tobd, VQI ... 2. U Þbl ~ Totlll, VQI - 0.00 bÞ R,c!$Ct T~ . Vol .. 0,00 bbI t:;/W loo With RI!id Dye: ~ Tatal, Val - 41.06 bbl Start Mud Þu¡¡;h 10.5' Not Going Thru NRD Drop Bottom Plug ~,.ntÆtf, VOl... 66.0.11 bbl Start lead Cement Gt;JOd I1!:bJlfI:õ O:mt:qt TœnpOown Holo-16 Del) S\oVItctl Slot ; j04 IIbls miX water. Reset Total. VOl = 423.53 bbl Ðab:JI Up Tìdl. ~ rumplpg -0,11 ComICnt, DroP Top PI~ PlulI Wt:rmllllll ~ Totaf, VOl '" 10!M6 bbl Re!iIeI:. Tetal, VOIu 0.00 bill 2 Nt.S Cm10nt on ~ of plug Waccr BehInd. ,'-" .- ---~..-'-. i1/.191200118::I,O:49 SdO HH~HH~1'H~S 8SY9 9LL L06 XVd 9C:YY QHM 6006/60/YO ) J Scbllllbepgep Cementing Service Report Wldl --c¡¡¡ïøm.r· '.' PHilLIPS p~~Ô~e~SM .COMPANY .' -- -- . L~CBtIønOIlllGal) ..---., - . Dowen L'JC8llon "ðþ'N~r', . .·~QÔ93$.O' , . jOb start -.- Fll!!lld Hansen #1 1 I48MFSL,1527"FËl SEC2,T4SA15' Kenai, AK 2001.Nov-19 --- .. I F'1;lIm~IIf;1ß ~meJ"(ype .. D~~ion Bit ~ï.¡Z;---·I·'·-W;11 MD . WQI TvD E;xploratioo i Dirty-5and~~o~.e ... .___ __-'!2~~ in j _ ~.200 11 [ ..~ _Point _L=~~~~_____ I·.... psi ~~...1'- BHCT 88'F .. Pð.,..rft.~. ;üft.~. DI'II~ For I Sl!!rvlco VI~ .' :...... ..:" :': :'::{':" :¢,8sJ'ngn.iner·: ;, :. '::;:' :.. ,", ': . ...: '..; .:"" : NABORS 273 Oil ; Land: ~a~~~tl "--1-""':$1z~¡;'" .:.,. ··W(lI~ht,·IÞm·" Grade ! Th';;d-- -'~~-----l WBIIType 700 -20 -- 106_5 Bull .----.-.-. I Max.DenslIY E:xP~:~~C):SCOSlty" :...51.~~: "':''':~+~''~~~Lib¡n~h-I~~:PIP9.·.1 " ~~~~.. ",: ~~'~':~1 9.951b/gal 55 Cp Depth. . SIw.I~ -~ht:'ibift..·, .."~~~... ,. '~~a~-l j;;¡;TŸP;-'-~---' .--.- '--":ïöoo 5.5 26.1 S-135 -- 'HT-55 ....-.. ."..~,.I..__..., .-. .--¡ : ::;.; "::: :~:":::.~ :" ""'''pei1c,rät}orisibpen Hoië . ÐotIQ~ ft :. ~p ' I NO. of Shots TOt8llnlel'\li!l~ TOp,tt COUl'ltV Alg Name I c,;faho~ 20m' DrlJllng fluid Type Other SIIIIn'lclIII Ultl!t Cementing Gem Surface Casing Max. Allowed Tubing PntlSlSu-;;--M~~. -Äii~~d Än~. p~-;;;¡; T- WellHNd Conneçtlon 2500 psi psi I Double cement hea ~rvlce In~tr\lc1lon8 -. '" -. , Provide Cement,Equlpment&Personnel For 2 Stage 13-3/8 Surfaoe Casing. DJpm.t.r TI'fISI DoW~ PI$p 4.'~~tmvn1 Packer 1"VPB In Packë¡: Depth 7~.4 bbl CaallJi iiol. AnnUlar Vol. bbl ni 4 bbt bbl ca81~ubll1g·S.~~~ ~ . ...- i HJ;¡h.. voi;~;ëin;;l.llllt.~ pnQrtl;;l Clmtntlng¡;¡¡ Casing TOOlS Squeøzø Job I Ufl PÑIII&UI't: - - ------ psi Shoe Typo; .~,....-. ~Io:~t Squ88m Type pipe Rot81ecl_D._ . _ . ... Pipe RaClpt¿~t~d1:r $fIr;¡,O.pU¡; 51 ¡;9 ft Tool Type: ---.. No.C.ntrallzøra~ __._ _~~.. .~~~..t~~~:.. ··1~-·" . .I~~~omp!l,Iør. ..'-", ~lIIg.TDoI"'vpe Tam Po~~. TOOID6pth: fi··- ¢errMÞnt "'Iact Type; Double St.,e Tool Depth; 10CÞ:! It 'T';¡¡ Plpa $120: in Jclb Scheduled· Fðr.: .... ---- T ÞrI~d (In LoWltlon: I ...." Location: CðllllrTVs*"'- ...--.- Flol~t T.II Pipe Depth: -- ft· ..... 11/18/2001 18:00 2001-Noy-18 18:00 2001·Noy·20 4:00 -·c-;ii;i:k.pÏh·~"·"·--· 50f~~ft Gcp:Tot.IVOI; bbl , :~~tü. '.: ~l1~e ';;;:::;.' :~O~~I~>.' .,-)f~~~1ty .' ·.:.VOIUmo ..-" ,0 ': ;,:,:::. :'~.;:; '~:~:':.: :;';: ..: :.': (.)' 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I _~PC;)l.:Nov-19 15:33 379 ~.__~·.l. . 12.16 54.5 i 0 0 (f ._.___ 20m -NOV-19 15:34 352 6.1 12.88 60.7 0 0 (I 2001-Nt?y-ï~ 15:35 347 "š-:--7l- 12.07 66.6 0 0 I) ~~1-Nov-19 15:36 365 ~.7 12.72 72.3 0 0 I) 3001-Nov-19 15:37 356 5.7 1.2.~. _ _. 78.0 0 0 I) 2001-Nov-19 15:38 356 5.7 12.36 83.7 0 0 I) 2001-Nov-19 H:j:39 . 35Ó--¡- 5.7 12.65 89.4 0 0 C -. .. - 2001.:~.ov·19 15:40 342 5.7 __. 12.4?. .... 95.1 0 0 ._...-,~~ . 20º1.-,~ov-19 15:41 333 5.7 __._. ,_,!Æ~~ 100.8 0 0 I) 2001-Nov-19 15:42 333, . . ..._.~.:.~ 12.48 106.5 0 0 0 2001-Nov-19 15:A3 __~~4. 5.7 12.32 112.2 0 0 (] 2001..Nov-19 ~?:44 320 5.7 12.31 116.2 0 0 0 2001~_~v·1.?_ 15:44 Good retums 2001-Nov-19 15:iJiI __ 32q..._ ... 5.7 12.30 117.9 0 0 (~___._. . 2001·NOV-1.~. 15:45 315 5.7 12.44 123.6 0 0 (~_.._..." 2001-NO\.~~~.. 15:46 315 5.7 _ _.12.47 ._... 129.4 0 0 0 ~~~ov-19 15:47 315_...... 5.7 12.46 135.1 0 0 (J _~OOJ14.~-19 15:48 315 5.7 12.53 1 AO.8 0 0 (I ~1-Nov-19 15;4?.. ß~~.... _ _ 5.7 __...:-. 12.81 146.5_...., .. ...~._"._ 0 .-l~...... -1 2001-Nov-1£..15:~O ..._ 310 _____ 5.7 12.53 ._____~9?·~. . ._..--2- 0 (I, "..___.._._._.._..m_.~~. ~,~ I ..2001-Nov~~.; 15:51 __~.___......~:.?... . 1.2:!.~ .. ~5a.o 0 _--º-_.. _.5~._.__.____... _.. : 2001·Nov-19 15:52 297 5.7 12.66' 163.7 0 _____..9_.., _.._~~_______". __.. ...., Jiõò 1~Növ-19 _.~ 5:53- -.. .. ~~?_. ~ ..~.... 5.7 ..__12.40-" OM 169.4 0 0 _--.f'._. 2001-NOV-1Y 1~:~____283 .~.._ 5.7 ___ ..1J.:~~.___.... ~~~.:L_.__-º-_--º--.. c. ....____.__.. ~.11:'l~v-19 15;55 278_ 5.7 12.47 180.9 .____~...., . º._---..f.__,__. . 2001-Nov-19 15:56 269 . 5.7 ", '12.26 186.6 0 0 . . ç ::~::: ~{: .~~ t·__·t~_··· ;~: ::~ ~ ~ . ~-_._~-~~~~-_..... -. 2001-Nov-19 15:59-" '''278 : 5.7 12.58 203.9 0 0 - '---0'-·"-"--' . 2åol-Nov,-19 -i6:ao 2iã-' "F- f!:! _ 12.53 209.3 0 0 0 . ....- . --. -.. ..... ... . 20q 1 ~f\!Q~- ~ 9, 16:00 I. . .____....~-_=~··.~1 !.. ... ___._.._ Cem~T~~ Do~- Hole=78 Deg , 2001-No~-19 . ïô:oo I 278 ¡ 5.7 I 12.53 209:6" -"!----·õ--n--·l·· ··..·ö· I 'ö . n .. -.-.-... ..- . - ,,_., j. ----... -... 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O:=~_..... -.-.- - ..- .. .?OOT..Nov.20 J151 ,." __gz. i 0.0 I 12.06 158.7 0 .. .º. ...__----º .__._... ..... ._..._ 2001·No~-20 ! :51 I... ] . . ... -'-...___ _ .... .. . .. Shut Down Batch Up T~~_ No\' 20,2001 WRS3 v3.2.S'\ Page 6 of 8 ..... ._.._~ " _... . ..' ____ _'I n_..._ . - ..---- -----.---.. .. . ......-.--- ..-..... ...- Stort Mixing Lead Slurry ---- ....¡ ... ') ') ') ) well . -.... - -.--. . --. - . ..-. ..-... ..-. . i:i~d- . - sendGII Data . CuåtÕmar -- .-- ,-- - -, ..... liltlb'16.1'm!JW· .....~ ._,_.:~._..,".. HanS~nftU1.. . . -,-_...._~~~~~... . .. 01.~~OV~~:...... " :HlLL~~S~~~:'LEUMCO~~~.._.. [,,:.:.(~~~,~~ .... ~....,.,,:~...... ~~:..¡. .....;~ .J~~". .:'.:':3',' ::¡:~\W··.'·· . :!:·;1;,~~,~ji?!~t:;:¡;t~]¡;~:ìi~:·'~..··'::. ~~~~:;:~¡:::!:(~..'..:; .~OO~-Noy-.20 1:5.1.. .....~_~_.._____ .2,:9__..._...J2.21 i 15~:? 0 0 ._..g....._.._.... '. ........__...__.. 2001-Nov-20 _]].~~ AD 0.0 J. .?~~~_ 158.7. . 0 0 _ ~~_ ... . ._.. _.__.___._.....: 2001-Nov-20 1:52 ___....__._ .. 0 _..._.. Reset Total. Vol =:=.158.69 bblJ ~-º!flO~-20 1:52 45 __, __._~<!_..... ... _£:.54.. 158.7 __-º--.____ 0 (~.. . ______n_ _...._.. ._J 2001-Nov-20 1:53. ..._. .~? 0.0 ..1...9.86 0.0 0 0 :, ~001-Nov-20 ~ .:54 . 45 ..._ 0.0 __._~ 11.-44 0.0 __.. ....... q._ 0 ;~ ___. .__._ _.___ .2001.~ov-20 1:55 49 ~!L_..,___.1_~.'.1? 0.1 0 0 ]. . _______.. . 200 l-Nov-20 1 :56 77 1. 7 15.23 1.8 0 0 :1 .----.--...... 2001-Nov:?0 1:5~.:. ... !~~, .:. .m?:!__ 15.29 3.8 0 0 J 200 ]_:~ov-20 1 :~~... ... ._ .146 _ i 2.7 15.99 6.6. 0 0 i] 200!.:!.'!o,:,-20 1:59 397 __?~... ... 15.9-? 11.9 0 0 I) 2001-Nov-20 2:00 352 5.6 15.08 17.5 0 0 (I 200 '-Nov-20 j~q.~ .. i Òtj'-- 1.8 ) 6.38 20.8 _.0. . 0 (I 2001-Nov·20 2:02 54 0.0 15.96 21.3 0 0 (I -- II ____'I 1Ç91~~ov-20 2:03 59 0.0 15.65 21.3 0 0 I) 2001-Nov-20 2:04 59 0.0 15.73 21.3 0 0 CO ,I' .,......_ ..__..... 2001·Nov-20 2:05 11.4 1.7 15.77 22.7 DOC 2001-Nov-20 2;06 36 0.0 15.76 24.4 0 0 C 200 l-Nov-20 2:06 200 l-Nov-20 2:06 2001-Nov-20 2:06 59 0.7 15.75 24.4 0 0 () I.. _______ 2001-Nov-20 ~,:2~..._.___45 0.7 15.75 0.0 .--..._.2 0 () 2001-Ngv-20 2:07 159 4.9 15.75 3.9 0 0 q__.... 2001-NoY-20 2:08 2~........ ....._~__ 15.75 8.8 0 0 () 2001-Nov..20 2:09 246 4.9 ___ 15.7~... ... .).~.8 0 0 () 20Dl-Nov-?0 2:10 ~_._..._ 4.9 __. . .__..L~..?~ '.. .!.~_ 0 0 (Ii .._..__ _____. 3pQl-Nov-20 2:]1... ..~~5 .... _ O.Q. ._..__.__15.73 ._~ 0 _.___ ....~_ 0 ___. ..__. ~OOl-NoY-20 .2:~_L,. n, . .......__._.. __._____.__... OM' ..____. ShutDo~_.._.. 2001-Nov:?~. ~:!.~_..___.~,05 ._.__~º_...___.._ 15.73___. ...,g~:~. 0 0 (~___ _._ .. ......______. 2001.Nov~20 2:12 __..._ ~~pp~d ~cqulsltlon 2001-Nov~2Õ' 2:" if .. __m.. ---r----- ..,.---.-..- .... .. Storted Acqulslllon ::~~:--~:~:I-=+a~F1· ~:~ ::~., ~~:~"--~--=~.., ~: ,. ...-,--,------, 2()()1-NOV~~~ 2: 14' - .... -..-_·-t-.-~_·.~. --, ..,-: -..- n. -f ' . . . . . ..1 .~. ..- '---=.~~:~-~.. Pressur~ Up ~.an .._. ~=---=-=-=~ ,~OOl-No"-20 .1.:,14. 187.. . . __ 0.~.__._.._~4 0.0 .._. ~ ..... .P.. . .!L__-,---.f...___ ..._.. ..... . . 2Ç9.1:-Nov·20 ?;.~ _ 1084 _-º=º-___. 8.84..__ 0.1 0 0 C 2OO1-Nov-20 2: 16 31 0.0 8.80 0.1 0 0 ( 20Ó1-Nov-20 2:16 . Î . -..-- - .-.. .---. -.---. - . . _u. Bleed Off ¡;;.~~~.~~-;;. . . ,- .-.-.-----.-1-----. ... ..--____.____._..,... 2001-Nov-~O 2:.1.~..__.~~_.__~._t. '~'!~---i 0.1 0 O~.. , .. ._._.... __........... .~l-No~·20. 2: 17 .~. j 0.0 . _~:?5 .nj.._---º:L. 0 0 0 . .. .._ _,__ . _.... 2001-~ov-2a 2:18_. ...31 r. ~Q.._ . ..,J!:~ 0.1. .~_.... ,0 _º-___º.... "._. _ ._..._ .u_ 2001-Nov-20 2:19 31 0.0 8.67' 0.1 I 0 0 0 , ?OQl-NO'{-2-Õ- 2:20._ _ _. .?2·"- 0.0. .1. _ _8..:..~__~~~,~· 0.1 .~. ~r~' 0 .9. - -"'-,-- -.-º ....-- Sh-e-ar" D....II. ... . ..._~ 2001-Nov-2D 2:20 r :. PV 2001-N.9,v:2ü _2:20'1 ... -434-=-.-·Õ.Õ·· ' '8:62, ~, 0.1 --,.... 0 __.00 _ 0 0 _.__~._.:=-.'. .~. ~1-Nov-20.. 2;.21 I ~~~.._ 0.0 1_. 6.57 u--ri ..._9~3 ¡. _-º- 0 0 . . _____._.. 2001-Nov-2.Q 2:?? .!._.__ 68 __QR...._.... ~:.?5 0.3..... +- 0 0 o. ... _.__. ..__..__._..._ 2001-Nov-20 2;23 . I Job Over 2001:Nov-20 2:23' 63 '--M-'~- 9.92 0.3! 0 0 "0'" - - .. --.---- J ..2001-NoV-2Ò 2;~~1- 63 [. _ _ 0.0 -·~.1_ '-9:ä3 0.3 'r'- 0 0 .¡--". 0 ...._--~~~~~_.. ._._.... .. - ¡ ........ ,_,. ""I . -------...I . ------.-- .-----..... -- .....-..., .. start Displacement _. Reset Total, Vol = ~..~? ~ .-- . ....--- -- Nov :20~, WRS3 v3.2-Sn page 7of8 600 [f] SdO H3f>H3ffiU11H;)S 8ST8 9LL L06 XVd Tt:TT GaM 6006/60/TO 8918 9LL L06 XVd It:ll GaM ZOOZ/ZO/I0 Page 8 of 8 ~ Job Comp~~--, Ib/gal bbl SdO H3~H3mul'H;)S 010~ KQ:;tiel, Richard i 0 Clrcul,~~lonLoat, ft I bblL IVrI .~ Cl~løb:l~ tQ Surf,,"? Volume o Washgd Thru Peril. Yo Densltv 744 .. OM ] Brea.l<do ,1~1 Fh.lÎd Volume ,.,2 100 ..._._J__.... Volume o{ Fluid i~é-ötéd~"'bbi'-"- Mud Spllc;m' 1 .\ 'M':':J51\~~. ",' . -." 'I ,I. I ... I. .' . r I .1.... .j --..... ! JøÞ.~"'l!IfMIr '. . ~ .~,:,:..;.*~D ':':: . 'r' '.- - . - , ' CI IL -, I..~ . - PHILUP6 PETAOI.EuNI COMPANY , ..... .' ,0....·: .' :11 cwtomlilr ') "'pöst Job ~ummary .-.-..--. .._. Ävëra:gê"Pump RatéŠ. bpm' . .. . ..'....¡ N2 . Mud MlIXlmum ABle j' Total 8Iurry .. ¡ ,,__1.. 6.5."._ TtEtatilig Pressure Summaty, psi I Anllll AVøm\18 Bump Plug to breakdown 3000 ,J. , ..~ _... I.__~oo _.. ._~~.. I Ayg_ N2 Percent Dt!I:!õlgl'll!ld Sluny VDIU~ DI$pltlCiJ;lmant ,. 715 bbl f 754 bbl CUSIOlMr tll' ~QriZlld RøpRls9ntatlw I Dowell supervisor ~~!~~~, ~~~!'}'L m_ _ ._____ Mix Water Temp 90 (IF Ty~ 715 0,' ., ~rŸtCIJ Dille I o I 32J·No"" 19 VoIU~·· (J Nov 20,,2001 WR53 \13.2-SR Max.hnul'l'l 5.7 Slurry .,bbl l~gaI' ·bblfmln Date Time TreBling . "'I' PrülÚI1I 24hr clock psi, éxploralloFl OMslt, Flow Ral. I-fsllr.en If' II' F1.ICI Well _",_.". ._.. ... - ..... t. . ---- -...., -., ) CASING TEST and FORMATION INTEGRITY TEST Well Name: Hansen #1 Date: 12/29/2001 Supervisor: Springer/Swenson o Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 47# & 53.5# L-80 SL-Boss Casing Setting Depth: 16,825' TMD Hole Depth: 16,846' TMD 6,695' TVD 6,7011 TVD .- Mud Weight: 9.0 ppg Length of Open Hole Section: 21' EMW= Leak-off Press. + Mud Weight = 1,327 psi + 9.0 ppg 0.052 x TVD 0.052 x 6,701' EMW for open hole section = 12.8 ppg Pump output = 0.1008 bps , JI.".I ~I: I -_____ 2,300 p~i . ¡ 2,200 psi I 2,100 psi ! 2,000 psi W 1,900 psi c:: 1,800 psi ::> 1,700 psi ~ 1,600 psi W 1,500 psi c:: 1,400 psi a. 1,300 psi 1,200 psi 1,1oopsi 1,000 psi - 900 psi 800 psi 700 psi 600 psi - 500 psi 400 psi 300 psi fl· . 200 psi i! 10g ~~: ! ¡ : " j ! : ~ ~ ~ ~ ~ N NNW W ~ ~ ~ ~ ~ m m m ~ W ~ ~ ~ ~ W ~ ~ m w w ~ ~ ~ ~ W 3,200 psi 3,100 psi· 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi = =:("~I (.; I .-. Fluid Pumped = 5.5 bbl : 1~!1I11H!1II¡l!ItmjHljlll!m!lIljlllpl!!IU'IH!HHIHfllllllllllll-~-==-- 1~~'t'*~T;t".'~'t'¡)f*"4: ¡ ~ ¡ . j , :~-==ITIME LINE -- ~--==~::-_- --;~~NE M'~JUITíTI-1 -~--=--~-~--i : ~ LEAK-OFF TEST ,-- ~CASING TEST . . LOT SHUT IN TIME -ci,- CASING TEST SHUT IN TIME ¡- -+- TIME LINE -- -- - I ----- - - ~ -L-l-- -.------- II --+ --------¿----:- I--~;-- ---- -Ï==~---~ -- ----=-:j~_=L_~__ I I . ---_.-------- -- ----- -----~----- 00 00 00 W W ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ V1 CD W -...J ~ g g ~ ~ ~ ~ ~ f.2 ~ :: ~ ~ ~ ~ ~ ~ ?ó (j ::j ~ ~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA , , MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE [~~~~~~~~~~~~~I~~~~~~!~~~~I~~~~~~~~~~~] [~~~~~~~~~~~~~~I~~Q~~~~~~~I~~~i~~~p-~~~~] L______________Lu~_~~_~~___L__!!!~p_~L)~-------un-----L.-~-:;-~~_~___L__~!!~_p.~Lj L--------------L--~-~!-~~-__1---~~~-p-~!-~ "\ ~_______________L--!!-:;-~~~---L--~~~-p-~~--.J L----------n--L--~-~!~~---L-~~~P~!.)o1~ ~---------------l--!~-~~~-_l---X~~-P-~~-nJ I----------------ln~-~-~!~~--L-~!!~p~!-)f. ~----------------L-!~-~~-~~-J---~-!~-p.~~-nj I----------------L--~-?-~!~~--J---!!~~p-~!-~ "'________________~--~~-~~-~~--~--!!~~XJ~~~-j L--------u----¡--~-~-~!~~--J---~J-~-p-~!-?~~----------------~--~~_~_~~~__~---!!~~-~-E~~-~ 1________________¡__~~_~!~:;___~---~~~J?-~~-:)þ\~-------nn---u~--~~_~~_~~__~---!!~?-~-E:;-~-~ L______________ln~~_~!~:;nJ___~~~_P~!_~ \L_________n_____L_~~_~~_~~__L!!~~~_E~~_J L______________L_~?_~!~~j___~~~p~!_)j~~---------------L~~-~!~~__L_!!~~~_E~i_j L______________L_~~_~!~~__L-~~~J?~!_~-n--------n---L-~~-~~_~~__L~!~~~-E:;LJ L---u----n---L_~~_~!~~__1---~~~p-~!-)j ~ ~---------------L-!!~-~!~~-_1--~!~~-~-E~~-j !----------------L-~~-~!~~--L-~~~p~!-~,S~--n-n--------~n~~-~!~~__~n~!~~-~-E~~-j ¡----------n----L--~~-~!~~--J---~~~p-~!--~ . $:_n____________~--~~-~!~~--~--~!~~~-E~i--j i-------_________¡__~~_~!~~__~--!!.g-~~-P-:;~-}'\punn--------~n~~_~!~~__~--~!~~-~-E~~-~ L_u___________¡__~?_~!~~__~--!!.gX~-P-:;~-~ w.bn____________~u~~-~!~~--~--~!~g-~-E~~-~ I----------------+--~~-~!~~--~--f!.~~~-P-:;~-~ ~~-------n-----~---------------~---------------n~ L.______________L_____~!n~_.l___L_____P_:;L> :iÙ-__n______n_L______________L_______________J ! ! 54 stks ! 1,307 psi : : ! ! ! :---------n-----T-------n------t---------------.-~ ~----nnn---r------------n-1------------n---1 : : 55 stks : 1,327 pSI , : : : : 1------------ ----.....------------.. --., ------ ---............ -- --1 ! ! ! ! ! SHUT IN TIME ! SHUT IN PRESSURE :----------------T---------------1-----------------1 r---Õ-.o-m-Cñ---r---------------1---3~Ooffpsi--l :________________~-- - ____u n n __{_______n - - - - __ n { ~___ __ __n __ - - - n ~ ___ ____ __n - - - - 4 _____ __ ___u_ _ _~_., : : : : : 1.0 min : : 2,950 pSI : :__________n_____I : : ~-----------.-n--~--n--------n-~-----n------n.--_I : : : : : 2.0 mln : : 2,945 pSI : . I . , I.________________~-------n-n---~n---__--n------_I L~~_~!_~~_~~~~_Ln_________n~~_~!_I_~~~_~~~~~E L_~:.2_~_i_~__L____n__n___.J__~!~~_~_E~~_J ! 0.0 min ! ! 1,327 psi ! ! 4.0 min ! ¡ 2,935 psi ! 1~~~~~~~~f~~~F~~~~~~~~~~~~~~¡~~f~~~~~~tr1 f~~~~~~~~~~~~~f~~~~~~~~~~~~~~~1~~~~~}~~~~F1 ¡---3~õ-ñiiñ---T-------------nr-:C28(fpšT-1 r---iõ-miñ--T--------------I--2~92õ-psf-l !---4~õ-ñiiñ--T---------------r-:c2-jõ-pšTl r---Š-.õ-m-iñ--T--------------,--2~92õ-psf-l ,---- n _____n - __.,..__ n_______n n T - __ n ______ __ __ - _, .. - - - - __ n_____ -- -r-- __ __ - - __ ___ __ 4- - ____n ___ - n _.- _., 1 5.0 min : : 1,260 psi I : 9.0 min : : 2,915 pSI : ------------:- - n+__ __ _________ __ f- -- - - ------ ----.- - ~ ~ --- - - - - n -- -;_ --- ~-- -- _ _ __ - - n___ ~- - - ___ n --- _ n-.--_I : 6.0 mln : : 1,250 pSI: : 10.0 mln : : 2,915 pSI :------------:----+ -- -- --------- -- t - -- n ----------.- -~ I- - - - - - - - -- -- -;- -- - ~n - - - - -- -- -- - -- ~- - - - n__ ---- - --.-- of L_~:9.._~!~n_L______________l__!!.~_~Q_P_:;_I_J l__1_~.:Q_~~~__L__nn_______L~!~~~_E~~_J ! 8.0 min ! ! 1,230 psi ¡ ¡ 20.0 min ! ! 2,890 psi ! ¡---9~õ-ñiiñ-nr--------------!--1-:23õr;sT-1 r--2Š~(fiñin--r--------------T-2:ã7õ-psfl ¡---iõ~õ--ñifñnf--------------i--1-;224-pšT-1 r--3-õ~O-iñin--r---------------r2~ãšõ-psrl 1------ -______ ___....______ -_......._ ___.__ __ __ __.......... __....... .._____ __ __...... __......... ___... ____.......... .....__...... ______ __.. ___~ ,-- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) lebluDlbepgep Cement Job Report ._._ _'M_'.'_' WeU H;.nsen #- 1 Field Exploration Engineer RIchard Koziel Country United States Time .. PrêS$ure I.:l/JIpDDI DI·1 "... 01:15:46 01;40: 53 02;06;00 02:31:07 02:56:14 03;21;21 03:46:2.8 04:11~35 ().4¡ 36:42 05;01;$6 hh:mm:ss WlW.RlCll~e.I..H> TOO III Client SIR No. .:Job Type JOb Date Rate } ~; 5 I '1 ¡.- .5: 'l3~~.\¡ o~ I o . ~: ~: ~ ~ ~ I " .,.--. I -¡: : o ; : : 4- . .~ ~bO : 0 .. . ~......".~ : '~ . , -:!f : :...dIIJ:- ! . :..__.~.: ~ ¡ ~ ~ =-- ! !··I~ ~ --.;.. ~.......-<: .... ~ S : : r hi JlJJ tm ~¡;œ 9~99 "18T ~IIOØ 0.0 1.7 3,3 5.0 &.7 ð.J 111.0 PSI 81M ,..--- SdO H3ÐH3aJ1l11ìH;)S ) Þhllllps 2200'9353 ::3 Cement II11:etmcdi~të 12-26-20Cl Density ~ : " \: q 15 11 U LB/G CemCAT v:t..O Messages Safety MIjI~lng Start C/Wl00 With Add!t -lave RetUrns Bleed orr PSI, Shut Down And Drop 1,5t Plug. kcsct: 'r'otiJl. Vol - 40.81 bbl Pressure. Te!lt Unët. Re!le.t. Total, VQI = '7.40 bbl Start HudpU!ih 12Lb Reset Total¡ Vol = 18.54 bbl Valve on vae trudr. stuck. Start Mudpu!lh!1 Re Zenxl Hö3ve Ftetumsl slow rate To get all MUdpUSh 8110t Down Batd1 uø Tub! (l...e3d) R~et Tal:õ!ll. Vol = 60.4:\ hbl St..1rt Pumping Lead cement A little Foam PrablRm. NRD foaming Out. Cement With Mud scales 12.3 Drop 2nd Bottörn ÞlUÇI. Start Tall Cement Reset Total. Vol = 43.09 bbl 2nd PlUQ went Reset Total. Vol = 97.96 bbl Drap '\"ap Plug PlIJ9 IN~NTIII $witch To water 8ehlnd Tum over To Rig Pomp~J.!. 25 SSTS 9LL L06 XVd SC:IT Œ3M ZOOZ/ZO/TO OllD2/Z002 11~D4~31 ) WRS.txt ) CemCAT 1.0 Cement 0.000 Mud 0.000 Spacer 0.000 Displacement 0.000 Max Pressure 23854244.000 Avg Pressure 3364095.000 Max Fluid Rate 0.055 Avg Fluid Rate 0.008 Time Treating Pressure Flow Rate Density volume mm:dd:yyyy:hh:mm:ss psi bbl/min lb/gal bbl 12:26:2001:01:15:46 27 0.0 -6.25 0.0 12:26:2001:01:16:01 safety Meeting 12:26:2001:01:16:01 27 0.0 -6.25 0.0 12:26:2001:01:16:16 27 0.0 -6.25 0.0 12:26:2001:01:16:27 Start C/W100 With Adds 12:26:2001:01:16:27 27 0.0 -6.25 12:26:2001:01:16:47 27 0.0 -6.25 12:26:2001:01:17:17 27 0.0 -6.25 12:26:2001:01:17:47 31 0.3 -6.25 12:26:2001:01:18:17 49 0.3 -6.25 12:26:2001:01:18:47 95 0.0 -6.25 12:26:2001:01:19:17 168 1.5 -6.25 12:26:2001:01:19:47 251 1.5 -6.25 12:26:2001:01:20:17 480 4.4 -6.25 12:26:2001:01:20:47 594 4.4 7.82 12:26:2001:01:21:17 622 4.4 7.84 12:26:2001:01:21:47 608 4.4 .7.88 12:26:2001:01:22:17 590 4.5 8.04 12:26:2001:01:22:47 645. 5.17.98 12:26:2001:01:22:59 Have Returns 12:26:2001:01:22:59 617 5.1 12:26:2001:01:23:17 548 5.1 12:26:2001:01:23:47 603 5.1 12:26:2001:01:24:17 649 5.1 12:26:2001:01:24:47 635 5.0 12:26:2001:01:25:17 617 5.1 12:26:2001:01:25:47 626 5.1 12:26:2001:01:26:17 741 5.1 12:26:2001:01:26:47 571 5.1 12:26:2001:01:27:17 612 5.1 12:26:2001:01:27:47 489 1.8 12:26:2001:01:28:18 526 1.8 12:26:2001:01:28:48 471 0.7 12:26:2001:01:29:18 429 0.0 12:26:2001:01:29:48 406 0.0 12:26:2001:01:30:02 Bleed off PSI. 12:26:2001:01:30:02 27 0.0 6.71 40.6 12:26:2001:01:30:18 27 0.1 6.80 40.6 12:26:2001:01:30:32 Shut Down And Drop 1st plug. 12:26:2001:01:30:32 59 0.3 6.59 40.7 12:26:2001:01:30:48 27 0.3 6.72 40.8 12:26:2001:01:31:10 Reset Total, vol = 40.81 bbl 12:26:2001:01:31:10 27 0.1 6.71 40.8 12:26:2001:01:31:18 31 0.1 6.94 0.0 12:26:2001:01:31:48 36 0.1 7.09 0.1 12:26:2001:01:32:18 49 0.3 6.83 0.1 12:26:2001:01:32:48 68 2.3 7.16 0.5 12:26:2001:01:33:18 68 2.3 7.00 1.7 12:26:2001:01:33:48 63 2.3 7.24 2.8 12:26:2001:01:34:18 68 2.3 7.25 4.0 12:26:2001:01:34:48 68 2.3 6.58 5.2 page 1 7.85 7.66 7.59 7.78 7.91 7.87 7.67 7.99 7.82 7.67 7.60 6.10 6.19 6.15 6.41 0.0 0.0 0.0 0.4 0.4 0.5 0.9 1.7 3.2 5.4 7.6 9.8 12.0 14.3 15.3 16.9 19.4 21.9 24.5 27.0 29.5 32.1 34.6 37.1 38.9 39.8 40.2 40.6 40.6 12:26:2001:01:35:18 12:26:2001:01:35:48 12:26:2001:01:36:18 12:26:2001:01:36:48 12:26:2001:02:49:34 12:26:2001:02:50:04 12:26:2001:02:50:09 12:26:2001:02:50:09 12:26:2001:02:50:28 12:26:2001:02:50:28 12:26:2001:02:50:34 12:26:2001:02:51:04 12:26:2001:02:51:35 12:26:2001:02:52:05 12:26:2001:02:52:35 12:26:2001:02:53:05 12:26:2001:02:53:35 12:26:2001:02:54:05 12:26:2001:02:54:35 12:26:2001:02:55:05 12:26:2001:02:55:35 12:26:2001:02:56:05 12:26:2001:02:56:35 12:26:2001:02:57:05 12:26:2001:02:57:35 12:26:2001:02:57:47 12:26:2001:02:57:47 12:26:2001:02:58:05 12:26:2001:02:58:35 12:26:2001:02:59:06 12:26:2001:02:59:36 12:26:2001:03:00:06 12:26:2001:03:00:36 12:26:2001:03:01:06 12:26:2001:03:01:36 12:26:2001:03:02:06 12:26:2001:03:02:36 12:26:2001:03:02:52 12:26:2001:03:02:52 12:26:2001:03:03:06 12:26:2001:03:03:18 12:26:2001:03:03:18 12:26:2001:03:03:36 12:26:2001:03:03:54 12:26:2001:03:03:54 12:26:2001:03:04:06 12:26:2001:03:04:36 12:26:2001:03:05:06 12:26:2001:03:05:07 12:26:2001:03:05:07 12:26:2001:03:05:36 12:26:2001:03:06:06 12:26:2001:03:06:36 12:26:2001:03:07:06 12:26:2001:03:07:36 12:26:2001:03:08:06 12:26:2001:03:08:36 12:26:2001:03:09:06 12:26:2001:03:09:36 12:26:2001:03:10:06 12:26:2001:03:10:36 12:26:2001:03:11:07 12:26:2001:03:11:37 ) ) WRS.txt 68 2.4 6.98 22 0.1 -5.59 63 0.3 7.13 40 0.3 7.15 27 0.0 8.08 27 0.0 8.08 Pressure Test Lines. 27 0.0 8.08 7.4 Reset Total, vol = 7.40 bbl 27 0.0 8.08 7.4 27 0.0 8.08 0.0 31 0.0 8.08 0.0 31 0.0 8.06 0.1 59 1.4 8.06 0.5 1052 1.0 8.06 1.0 1990 0.0 8.06 1.0 1977 0.0 8.06 1.0 3171 0.5 8.06 1.1 3428 0.0 8.06 1.4 3222 0.0 8.06 1.4 2942 0.0 8.06 1.4 2700 0.0 8.06 1.4 155 0.0 8.06 1.4 123 0.0 8.06 1.4 118 0.0 8.06 1.4 Start Mudpush 12Lb 118 0.0 8.06 1.4 118 0.0 8.06 1.4 127 2.0 8.06 2.0 146 4.5 8.06 3.7 146 5.2 8.06 6.2 146 5.2 8.06 8.8 146 5.2 8.06 11.4 146 5.2 8.06 14.0 146 5.2 8.06 16.6 146 0.0 8.06 18.5 146 0.0 8.06 18.5 Reset Total, vol = 18.54 bbl 146 0.0 8.06 18.5 146 0.0 8.06 0.0 valve on vac truck stuck. 150 0.0 8.06 0.0 278 1.9 8.06 0.5 Start Mudpush!! Re zerod 439 4.2 8.06 1.3 654 5.2 8.06 2.2 809 5.0 8.06 4.8 892 5.0 8.06 7.3 Have Returns! 915 5.0 901 5.0 878 5.1 841 5.1 841 5.0 851 5.1 832 5.1 837 5.1 860 5.1 823 5.1 823 5.1 837 5.1 800 5.1 791 5.1 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 8.06 page 2 6.3 7.1 7.2 7.3 7.4 7.4 7.4 9.8 12.4 14.9 17.4 19.9 22.5 25.0 27.5 30.0 32.6 35.1 37.7 40.2 12:26:2001:03:12:07 12:26:2001:03:12:37 12:26:2001:03:13:07 12:26:2001:03:13:37 12:26:2001:03:14:07 12:26:2001:03:14:37 12:26:2001:03:15:07 12:26:2001:03:15:37 12:26:2001:03:16:01 12:26:2001:03:16:01 12:26:2001:03:16:07 12:26:2001:03:16:37 12:26:2001:03:16:58 12:26:2001:03:16:58 12:26:2001:03:17:07 12:26:2001:03:17:37 12:26:2001:03:17:42 12:26:2001:03:17:42 12:26:2001:03:17:48 12:26:2001:03:17:48 12:26:2001:03:18:07 12:26:2001:03:18:37 12:26:2001:03:19:07 12:26:2001:03:19:37 12:26:2001:03:20:07 12:26:2001:03:20:37 12:26:2001:03:21:07 12:26:2001:03:21:07 12:26:2001:03:21:37 12:26:2001:03:22:07 12:26:2001:03:22:38 12:26:2001:03:23:08 12:26:2001:03:23:38 12:26:2001:03:24:08 12:26:2001:03:24:38 12:26:2001:03:25:08 12:26:2001:03:25:38 12:26:2001:03:26:08 12:26:2001:03:26:38 12:26:2001:03:27:08 12:26:2001:03:27:38 12:26:2001:03:28:08 12:26:2001:03:28:38 12:26:2001:03:29:08 12:26:2001:03:29:38 12:26:2001:03:30:08 12:26:2001:03:30:38 12:26:2001:03:31:08 12:26:2001:03:31:38 12:26:2001:03:32:08 12:26:2001:03:32:38 12:26:2001:03:33:08 12:26:2001:03:33:38 12:26:2001:03:34:09 12:26:2001:03:34:28 12:26:2001:03:34:28 12:26:2001:03:34:39 12:26:2001:03:35:09 12:26:2001:03:35:39 12:26:2001:03:36:09 12:26:2001:03:36:39 12:26:2001:03:37:09 12:26:2001:03:37:39 ) WRS.txt 809 5.1 8.06 42.8 786 5.1 8.06 45.3 805 5.1 8.06 47.8 818 5.1 8.06 50.3 791 5.1 8.06 52.9 732 4.1 8.06 55.2 672 3.4 8.06 57.0 603 2.8 8.06 58.6 slow rate TO get all Mudpush 626 2.8 8.06 59.8 594 2.8 8.06 60.1 503 0.0 8.06 60.4 shut Down 503 0.0 -5.59 60.4 503 0.0 0.23 60.4 503 0.0 8.71 60.4 Batch up Tub! (Lead) 503 0.0 8.57 60.4 Reset Total, vol = 60.43 bbl 503 0.0 8.02 60.4 503 0.0 8.22 0.0 503 0.0 8.33 0.0 503 0.0 8.38 0.0 503 0.0 8.48 0.0 503 0.0 9.70 0.0 503 0.0 11.60 0.0 Start pumping Lead Cement 503 0.0 12.79 0.0 370 0.0 12.64 0.0 352 0.0 12.17 0.0 384 0.8 12.27 0.1 466 1.8 12.33 0.8 535 2.9 11.29 2.1 461 0.0 13.88 2.7 475 1.4 12.82 2.7 567 2.3 12.42 3.7 571 2.3 12.76 4.9 603 2.3 13.13 6.0 590 2.3 12.50 7.2 603 2.9 13.20 8.5 617 2.8 13.26 9.9 580 2.9 11.60 11.4 530 1.8 12.32 12.5 516 1.8 12.78 13.4 516 1.8 12.99 14.3 558 2.9 11.91 15.5 571 2.9 5.10 16.9 576 2.9 12.88 18.3 590 2.9 12.85 19.8 516 2.9 12.03 21.2 507 1.8 13.39 22.4 507 1.8 12.51 23.3 471 1.8 11.02 24.2 484 1.8 12.86 25.2 A little Foam problem. 503 1.8 13.22 498 1.8 12.86 503 1.8 12.72 484 1.8 11.71 466 1.8 12.05 439 1.1 11.62 425 1.1 13.54 443 1.1 13.37 page 3 25.7 26.1 27.0 27.9 28.8 29.5 30.0 30.6 ) ) ) WRS.txt 12:26:2001:03:38:09 503 1.8 12.27 31.4 12:26:2001:03:38:39 489 1.8 12.05 32.4 12:26:2001:03:39:09 452 1.1 11.71 33.2 12:26:2001:03:39:39 425 1.1 11.36 33.8 12:26:2001:03:40:09 406 0.0 11.31 34.2 12:26:2001:03:40:39 397 0.0 11.47 34.2 12:26:2001:03:41:09 388 0.0 11.53 34.2 12:26:2001:03:41:39 384 0.0 11.57 34.2 12:26:2001:03:42:09 384 0.0 11.59 34.2 12:26:2001:03:42:39 379 0.0 11.58 34.2 12:26:2001:03:43:09 379 0.0 10.98 34.2 12:26:2001:03:43:39 379 0.0 12.09 34.2 12:26:2001:03:44:09 402 1.6 11.51 34.6 12:26:2001:03:44:39 416 1.6 9.22 35.5 12:26:2001:03:45:09 443 2.1 10.68 36.3 12:26:2001:03:45:40 466 2.3 10.69 37.5 12:26:2001:03:46:10 448 3.4 10.27 39.0 12:26:2001:03:46:40 411 0.9 10.63 39.8 12:26:2001:03:47:10 443 2.6 8.91 40.8 12:26:2001:03:47:16 NRD Foaming out. 12:26:2001:03:47:16 429 2.6 10.85 41.1 12:26:2001:03:47:40 443 2.9 7.87 42.2 12:26:2001:03:47:42 Cement with Mud scales 12.3 12:26:2001:03:47:42 452 2.9 8.47 42.3 12:26:2001:03:48:10 411 0.0 10.24 43.1 12:26:2001:03:48:40 384 0.0 6.78 43.1 12:26:2001:03:49:10 370 0.0 6.46 43.1 12:26:2001:03:49:40 361 0.0 8.89 43.1 12:26:2001:03:50:10 356 0.0 10.44 43.1 12:26:2001:03:50:40 347 0.0 10.62 43.1 12:26:2001:03:51:10 347 0.0 10.65 43.1 12:26:2001:03:51:40 342 0.0 11.11 43.1 12:26:2001:03:52:10 338 0.0 11.29 43.1 12:26:2001:03:52:40 338 0.0 10.92 43.1 12:26:2001:03:53:10 333 0.0 10.89 43.1 12:26:2001:03:53:40 333 0.0 10.87 43.1 12:26:2001:03:54:10 329 0.0 10.86 43.1 12:26:2001:03:54:40 329 0.0 10.85 43.1 12:26:2001:03:55:10 329 0.0 10.83 43.1 12:26:2001:03:55:14 Drop 2nd Bottom plug. 12:26:2001:03:55:14 329 0.0 10.83 43.1 12:26:2001:03:55:40 324 0.0 10.82 43.1 12:26:2001:03:56:10 324 0.0 10.81 43.1 12:26:2001:03:56:40 324 0.0 10.82 43.1 12:26:2001:03:57:11 324 0.0 10.81 43.1 12:26:2001:03:57:41 324 0.0 10.80 43.1 12:26:2001:03:58:11 320 0.0 10.78 43.1 12:26:2001:03:58:41 320 0.0 10.79 43.1 12:26:2001:03:59:11 320 0.0 10.78 43.1 12:26:2001:03:59:41 320 0.0 10.76 43.1 12:26:2001:04:00:11 320 0.0 10.76 43.1 12:26:2001:04:00:41 315 0.0 10.76 43.1 12:26:2001:04:01:11 315 0.0 10.76 43.1 12:26:2001:04:01:41 315 0.0 10.75 43.1 12:26:2001:04:02:11 315 0.0 10.75 43.1 12:26:2001:04:02:41 315 0.0 10.73 43.1 12:26:2001:04:03:11 315 0.0 10.75 43.1 12:26:2001:04:03:41 315 0.0 10.73 43.1 12:26:2001:04:04:11 315 0.0 10.73 43.1 12:26:2001:04:04:41 310 0.0 10.73 43.1 12:26:2001:04:05:11 310 0.0 10.73 43.1 12:26:2001:04:05:41 310 0.0 10.75 43.1 12:26:2001:04:06:11 310 0.0 10.76 43.1 page 4 12:26:2001:04:06:41 12:26:2001:04:07:11 12:26:2001:04:07:41 12:26:2001:04:08:11 12:26:2001:04:08:36 12:26:2001:04:08:36 12:26:2001:04:08:40 12:26:2001:04:08:40 12:26:2001:04:08:42 12:26:2001:04:09:12 12:26:2001:04:09:42 12:26:2001:04:10:12 12:26:2001:04:10:42 12:26:2001:04:11:12 12:26:2001:04:11:42 12:26:2001:04:12:12 12:26:2001:04:12:42 12:26:2001:04:13:12 12:26:2001:04:13:42 12:26:2001:04:14:06 12:26:2001:04:14:06 12:26:2001:04:14:12 12:26:2001:04:14:42 12:26:2001:04:15:12 12:26:2001:04:15:42 12:26:2001:04:16:12 12:26:2001:04:16:42 12:26:2001:04:17:12 12:26:2001:04:17:42 12:26:2001:04:18:12 12:26:2001:04:18:42 12:26:2001:04:19:12 12:26:2001:04:19:42 12:26:2001:04:20:13 12:26:2001:04:20:43 12:26:2001:04:21:13 12:26:2001:04:21:43 12:26:2001:04:22:13 12:26:2001:04:22:43 12:26:2001:04:23:13 12:26:2001:04:23:43 12:26:2001:04:24:13 12:26:2001:04:24:43 12:26:2001:04:25:13 12:26:2001:04:25:43 12:26:2001:04:26:13 12:26:2001:04:26:43 12:26:2001:04:27:13 12:26:2001:04:27:43 12:26:2001:04:28:13 12:26:2001:04:28:43 12:26:2001:04:29:13 12:26:2001:04:29:43 12:26:2001:04:30:13 12:26:2001:04:30:43 12:26:2001:04:31:13 12:26:2001:04:31:43 12:26:2001:04:32:14 12:26:2001:04:32:44 12:26:2001:04:33:14 12:26:2001:04:33:44 12:26:2001:04:34:14 12:26:2001:04:34:44 ) ) WRS.txt 310 0.0 10.77 43.1 310 0.0 10.47 43.1 310 0.0 10.72 43.1 310 0.0 10.76 43.1 Start Tail Cement 310 0.0 10.37 43.1 Reset Total, vol = 43.09 bbl 310 0.0 10.69 43.1 310 0.0 10.68 0.0 310 0.0 10.19 0.0 310 0.0 10.62 0.0 297 0.0 10.02 0.0 265 0.0 10.05 0.0 265 0.0 9.99 0.0 265 0.0 9.89 0.0 265 0.0 9.82 0.0 265 0.0 9.93 0.0 265 0.0 9.94 0.0 301 0.8 10.24 0.2 2nd plug Went 347 1.1 342 1.1 365 0.0 352 0.0 347 0.0 342 0.0 338 0.0 338 0.0 333 0.0 333 0.0 329 0.0 329 0.0 329 0.0 324 0.0 324 0.0 324 0.0 324 0.0 324 0.0 324 0.0 324 0.0 333 0.0 374 1.8 370 2.9 393 2.9 686 3.2 612 2.0 695 3.2 686 3.2 722 3.2 754 3.2 709 3.2 704 3.2 681 3.2 699 3.2 695 3.2 892 4.9 727 5.0 983 5.0 672 5.0 722 5.0 677 3.2 603 3.2 594 3.2 9.59 10.02 9.92 10.05 10.25 10.28 10.22 9.47 9.10 4.39 0.04 0.23 0.72 0.01 0.01 0.01 8.55 7.80 8.44 11.07 13.84 15.87 16.63 16.08 16.09 15.73 15.80 15.45 15.94 15.91 15.68 15.86 15.73 15.96 15.82 15.58 15.97 15.88 15.17 16.23 15.69 15.43 15.65 page 5 0.6 0.7 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.1 1.6 2.6 4.0 5.4 6.7 8.2 9.8 11.4 13.0 14.6 16.2 17.8 19.4 21.0 23.2 25.8 28.4 30.9 33.4 35.4 37.0 38.6 ) ) WRS.txt 12:26:2001:04:35:14 603 3.2 15.87 40.2 12:26:2001:04:35:44 585 3.2 15.68 41.9 12:26:2001:04:36:14 585 3.2 15.81 43.5 12:26:2001:04:36:44 571 3.2 15.75 45.1 12:26:2001:04:37:14 585 3.2 15.81 46.7 12:26:2001:04:37:44 571 3.2 15.82 48.3 12:26:2001:04:38:14 562 3.2 15.75 49.9 12:26:2001:04:38:44 558 3.2 15.81 51.5 12:26:2001:04:39:14 558 3.2 15.75 53.1 12:26:2001:04:39:44 548 3.2 15.76 54.8 12:26:2001:04:40:14 544 3.2 15.84 56.4 12:26:2001:04:40:44 539 3.2 15.78 58.0 12:26:2001:04:41:14 526 3.2 15.84 59.6 12:26:2001:04:41:44 530 3.2 15.81 61.2 12:26:2001:04:42:14 516 3.2 15.71 62.8 12:26:2001:04:42:44 507 3.2 15.81 64.4 12:26:2001:04:43:14 503 3.2 15.75 66.1 12:26:2001:04:43:45 498 3.2 15.84 67.7 12:26:2001:04:44:15 489 3.2 15.71 69.3 12:26:2001:04:44:45 475 3.2 15.75 71.0 12:26:2001:04:45:15 471 3.2 15.84 72.6 12:26:2001:04:45:45 466 3.2 15.74 74.2 12:26:2001:04:46:15 457 3.2 15.75 75.8 12:26:2001:04:46:45 448 3.2 15.79 77.4 12:26:2001:04:47:15 443 3.2 15.78 79.0 12:26:2001:04:47:45 434 3.2 15.75 80.7 12:26:2001:04:48:15 434 3.2 15.73 82.3 12:26:2001:04:48:45 425 3.2 15.84 83.9 12:26:2001:04:49:15 416 3.2 15.75 85.5 12:26:2001:04:49:45 402 3.2 15.71 87.1 12:26:2001:04:50:15 402 3.3 15.87 88.8 12:26:2001:04:50:45 393 3.2 15.68 90.4 12:26:2001:04:51:15 388 3.2 15.74 92.0 12:26:2001:04:51:45 384 3.2 15.75 93.6 12:26:2001:04:52:15 384 3.3 15.75 95.2 12:26:2001:04:52:45 365 3.2 15.62 96.9 12:26:2001:04:53:15 182 0.0 15.49 98.0 12:26:2001:04:53:45 155 0.0 15.53 98.0 12:26:2001:04:54:15 150 0.0 15.52 98.0 12:26:2001:04:54:45 146 0.0 15.69 98.0 12:26:2001:04:55:16 141 0.0 15.71 98.0 12:26:2001:04:55:46 141 0.0 15.72 98.0 12:26:2001:04:56:16 141 0.0 15.72 98.0 12:26:2001:04:56:46 141 0.0 15.72 98.0 12:26:2001:04:57:01 Reset Total, vol = 97.96 bbl 12:26:2001:04:57:01 141 0.0 15.72 98.0 12:26:2001:04:57:16 141 0.0 15.72 0.0 12:26:2001:04:57:21 Drop TOp plug 12:26:2001:04:57:21 146 0.3 15.72 0.0 12:26:2001:04:57:37 pl ug WENT! ! ! 12:26:2001:04:57:37 155 1.2 14.43 0.2 12:26:2001:04:57:46 159 1.2 14.14 0.4 12:26:2001:04:58:16 164 1.2 14.75 1.0 12:26:2001:04:58:46 164 1.2 14.81 1.6 12:26:2001:04:59:16 164 1.1 14.85 2.2 12:26:2001:04:59:25 switch To Water Behind 12:26:2001:04:59:25 155 1.0 14.85 2.3 12:26:2001:04:59:46 173 2.4 14.87 2.9 12:26:2001:05:00:16 187 2.9 14.88 4.3 12:26:2001:05:00:46 141 0.0 14.88 5.1 12:26:2001:05:01:16 136 0.0 14.88 5.1 12:26:2001:05:01:41 Turn Over To Rig pumps!! 12:26:2001:05:01:41 136 0.0 14.01 5.1 page 6 12:26:2001:05:01:46 136 ) ) WRS.txt 0.0 13.73 5.1 page 7 Hansen #1 slot # 1 RT-Seabee 175.00m RT-MSL= 175.00m MD DEVI AZIMUTH TVDBRT TVDS X Y NS EW DLS VSEC m deg deg m m m m m m deg/1 OOm m ------------ ------------ 0 0 0 0 -175 168820.7 2144660 0 0 0 0 495 0 0 495 320 168820.7 2144660 0 0 0 0 741 1.6 32.3 740.97 565.97 168822.6 2144662 2.9 1.84 0.65 -0.28 835 1.8 348.4 834.93 659.93 168823.1 2144665 5.46 2.24 1.37 0.54 927 2 260.4 926.9 751.9 168821.3 2144666 6.61 0.37 2.87 2.73 1025 4.8 256.8 1024.71 849.71 168815.6 2144665 5.38 -5.31 2.86 7.2 1118 7.5 272.7 1117.18 942.18 168805.7 2144665 4.78 -15.17 3.41 15.66 1211 10 286.3 1209.1 1034.1 168792 2144668 7.33 -28.98 3.47 29.09 1307 12.8 292.3 1303.2 1128.2 168774.3 2144674 13.71 -46.83 3.16 47.86 1401 15.5 293.9 1394.34 1219.34 168753.4 2144684 22.75 -67.95 2.9 70.77 1495 17.8 296 1484.39 1309.39 168729.3 2144696 34.14 -92.35 2.53 97.67 1589 20.4 298 1573.21 1398.21 168702.3 2144711 48.13 -119.73 2.85 128.42 1684 22.7 298 1661.56 1486.56 168672 2144728 64.51 -150.54 2.42 163.31 1775 25 300.3 1744.79 1569.79 168640.4 2144747 82.46 -182.65 2.73 200.08 1866 27.7 300.8 1826.33 1651.33 168606.2 2144768 103 -217.43 2.98 240.41 1959 30.1 301.2 1907.74 1732.74 168568.3 2144793 126.15 -255.95 2.59 285.27 2052 32.8 300.7 1987.07 1812.07 168527.4 2144819 151.09 -297.56 2.92 333.7 2144 35.2 300.7 2063.33 1888.33 168483.9 2144846 177.36 -341.79 2.61 385.07 2239 38.4 299.9 2139.39 1964.39 168435.5 2144876 206.05 -390.93 3.41 441.9 2333 41.2 300.6 2211.61 2036.61 168384.4 2144908 236.37 -442.89 3.02 502 2426 43.2 300.9 2280.5 2105.5 168331.6 2144941 268.31 -496.58 2.16 564.37 2519 45.5 300.8 2347 2172 168276.7 2144976 301 .65 -552.38 2.47 629.27 2610 48.3 299 2409.17 2234.17 168220 2145011 334.74 -609.99 3.4 695.64 2704 51.6 297 2469.65 2294.65 168157.4 2145046 368.49 -673.52 3.87 767.58 2798 53.4 297.6 2526.87 2351.87168092.1 2145082 402.69 -739.78 1.98 842.15 2894 55.2 297.6 2582.89 2407.89 168024 2145120 438.81 -808.87 1.87 920.11 2988 57.7 296.4 2634.84 2459.84 167955.2 2145157 474.36 -878.67 2.86 998.44 3084 59.5 296.6 2684.85 2509.85 167882.9 2145196 510.92 -952 1.88 1080.36 3178 61.5 297.1 2731 .14 2556.14 167810.9 2145235 547.88 -1024.98 2.18 1162.16 3270 64.2 296.4 2773.12 2598.12 167738.8 2145274 584.71 -1098.08 3.01 1244.01 3362 67.4 297.3 2810.82 2635.82 167665 2145314 622.62 -1172.93 3.59 1327.91 3456 70.2 298 2844.81 2669.81 167588.6 2145356 663.29 -1250.55 3.06 1415.54 3551 72.9 297.9 2874.88 2699.88 167510.1 2145401 705.52 ··1330.15 2.84 1505.64 3660 73.4 298.3 2906.47 2731.47 167419.5 2145452 754.66 -1422.1 8 0.58 1609.96 3754 73.4 297.9 2933.33 2758.33 167341 .2 2145497 797.09 -1501.64 0.41 1700.03 3848 73.4 297.7 2960.18 2785.18 167262.7 2145541 839.1 -1581.32 0.2 1790.12 3944 73.4 297.3 2987.61 2812.61 167182.2 2145586 881.58 -1662.93 0.4 1882.11 4036 73.2 297.4 3014.04 2839.04 167105.1 2145628 922.06 -1741.2 0.24 1970.23 4130 73.2 297.7 3041.21 2866.21 167026.4 2145672 963.69 -1820.98 0.31 2060.22 4225 73.4 297.6 3068.51 2893.51 166947 2145717 1005.91 -1901.58 0.23 2151.21 4319 73.5 297.4 3095.29 2920.29 166868.2 2145760 1047.52 -1981.51 0.23 2241 .32 4412 73.3 297.9 3121.86 2946.86 166790.4 2145804 1088.88 -2060.45 0.56 2330.44 4508 73.5 297.9 3149.28 2974.28 166710.3 2145849 1131.93 -2141.76 0.21 2422.44 4603 73.4 298.1 3176.35 3001.35 166631.1 2145894 1174.68 -2222.16 0.23 2513.5 4697 73.4 298 3203.2 3028.2 166552.8 2145938 1217.04 -2301 .66 0.1 2603.58 4791 73.4 297.9 3230.05 3055.05 166474.4 2145983 1259.26 -2381.24 0.1 2693.66 4885 73.5 296.9 3256.83 3081.83 166395.5 2146026 1300.73 -2461.24 1.03 2783.77 4980 73.5 296.4 3283.81 3108.81 166315.3 2146069 1341.58 -2542.65 0.5 2874.84 5073 73.3 296.5 3310.38 3135.38 166236.6 2146111 1381.28 -2622.44 0.24 2963.95 5151 74 297.2 3332.34 3157.34 166170.7 2146147 1415.09 -2689.22 1.24 3038.79 5275 73.2 298.9 3367.35 3192.35 166067.3 2146206 1471.02 -2794.2 1.46 3157.73 5370 73.2 298.7 3394.81 3219.81 165988.8 2146252 1514.83 -2873.89 0.2 3248.66 5464 73.3 298.5 3421.9 3246.9 165911 2146297 1557.92 -2952.92 0.23 3338.65 5558 73.2 298.3 3448.99 3273.99 165833 2146342 1600.73 -3032.1 0.23 3428.65 5652 73.2 298.1 3476.16 3301 .16 165754.9 2146386 1643.25 -3111.41 0.2 3518.64 5745 73.2 297.8 3503.04 3328.04 165677.4 2146430 1684.98 -3190.05 0.31 3607.67 5839 73.3 297.9 3530.13 3355.13 165598.9 2146474 1727.03 -3269.64 0.15 3697.68 5932 73.4 297.6 3556.78 3381.78 165521.2 2146518 1768.52 -3348.49 0.33 3786.78 6025 73.6 297.4 3583.19 3408.19 165443.3 2146561 1809.69 -3427.58 0.3 3875.95 6117 73.3 296.9 3609.4 3434.4 165365.9 2146604 1849.93 -3506.06 0.61 3964.13 ) ) 6210 73.2 297.1 3636.2 3461.2 165287.7 2146646 1890.36 -3585.4 0.23 4053.18 6305 73.3 296.8 3663.58 3488.58 165207.8 2146690 1931.59 -3666.49 0.32 4144.15 6398 73.1 296.4 3690.46 3515.46 165129.3 2146732 1971.46 -3746.1 0.46 4233.16 6493 73.2 296 3718 3543 165048.8 2146774 2011 .6 -3827.68 0.42 4324.06 6586 73.1 296 3744.95 3569.95 164969.9 2146815 2050.62 -3907.68 0.11 4413.03 6678 73.3 296.3 3771.54 3596.54 164891.9 2146856 2089.43 -3986.74 0.38 4501.08 6774 73.6 296.1 3798.89 3623.89 164810.5 2146899 2130.06 -4069.31 0.37 4593.08 6868 73.1 296 3825.82 3650.82 164730.6 2146941 2169.61 -4150.22 0.54 4683.11 6962 73.3 295.6 3852.99 3677.99 164650.7 2146982 2208.78 -4231.23 0.46 4773.05 7057 73.1 295.8 3880.45 3705.45 164569.9 2147024 2248.22 -4313.18 0.29 4863.95 7150 73.2 295.8 3907.41 3732.41 164490.8 2147065 2286.95 -4393.32 0.11 4952.92 7245 73.2 296.2 3934.87 3759.87 164410.2 2147107 2326.82 -4475.06 0.4 5043.83 7339 73.1 296.2 3962.11 3787.11 164330.6 2147149 2366.54 -4555.78 0.11 5133.77 7432 73.2 296.3 3989.07 3814.07 164251.8 2147190 2405.91 -4635.61 0.15 5222.75 7526 73.4 296.4 4016.08 3841.08 164172.2 2147232 2445.87 -4716.29 0.24 5312.77 7619 73.1 296.4 4042.89 3867.89 164093.6 2147274 2485.47 -4796.05 0.32 5401.8 7712 73.1 296.7 4069.92 3894.92 164015.1 2147316 2525.24 -4875.65 0.31 5490.77 7806 73.3 297.1 4097.09 3922.09 163936 2147359 2565.96 -4955.91 0.46 5580.76 7900 73.2 297.4 4124.18 3949.18 163857.1 2147402 2607.17 -5035.93 0.32 5670.77 7993 73.2 297.7 4151.06 3976.06 163779.3 2147445 2648.35 -5114.86 0.31 5759.8 8088 73.4 297.9 4178.36 4003.36 163700 2147490 2690.79 -5195.35 0.29 5850.79 8180 73 298 4204.95 4029.95 163623.3 2147533 2732.07 -5273.15 0.45 5938.86 8276 73.1 298.1 4232.94 4057.94 163543.5 2147579 2775.25 -5354.2 0.14 6030.69 8370 73.1 298 4260.26 4085.26 163465.3 2147623 2817.54 -5433.57 0.1 6120.62 8464 73.1 297.9 4287.59 4112.59 163387 2147667 2859.7 -5513.02 0.1 6210.56 8557 73.1 297.8 4314.63 4139.63 163309.5 2147711 2901.27 -5591.7 0.1 6299.54 8650 73.3 298.1 4341.51 4166.51 163232 2147755 2943 -5670.34 0.38 6388.57 8743 73 298.3 4368.46 4193.46 163154.7 2147799 2985.06 -5748.79 0.38 6477.57 8835 73.3 298.3 4395.13 4220.13 163078.3 2147843 3026.8 -5826.31 0.33 6565.62 8929 73.5 298.5 4421.99 4246.99 163000.3 2147888 3069.64 -5905.55 0.29 6655.69 9021 73.6 298.3 4448.04 4273.04 162923.8 2147932 3111.61 -5983.17 0.24 6743.91 9115 73.1 298 4474.97 4299.97 162845.6 2147977 3154.1 -6062.57 0.61 6833.97 9208 73.1 297.2 4502.01 4327.01 162767.9 2148020 3195.32 -6141.43 0.82 6922.95 9302 73.1 296.8 4529.33 4354.33 162688.9 2148063 3236.16 -6221.57 0.41 7012.88 9395 73.2 296.7 4556.29 4381.29 162610.5 2148105 3276.22 -6301.05 0.15 7101.88 9487 73.4 297 4582.73 4407.73 162533 2148147 3316.02 -6379.67 0.38 7190 9581 73.2 297.3 4609.74 4434.74 162454 2148190 3357.1 -6459.78 0.37 7280.03 9675 72.8 297.7 4637.22 4462.22 162375.4 2148234 3398.61 -6539.52 0.59 7369.92 9770 73.2 298 4665 4490 162296.3 2148279 3441.05 -6619.85 0.52 7460.77 9864 72.7 297.4 4692.56 4517.56 162217.9 2148322 3482.83 -6699.41 0.81 7550.64 9959 73.4 297.7 4720.26 4545.26 162138.5 2148367 3524.86 -6779.98 0.8 7641.51 1 0053 73.1 297.6 4747.35 4572.35 162059.9 2148411 3566.63 -6859.71 0.34 7731.52 10146 73 298.3 4774.46 4599.46 161982.5 2148454 3608.32 -6938.3 0.73 7820.48 1 0238 73.5 298.3 4800.97 4625.97 161906 2148498 3650.09 -7015.86 0.54 7908.57 1 0332 73.5 297.7 4827.67 4652.67 161827.6 2148543 3692.4 -7095.44 0.61 7998.69 10427 73.4 299 4854.73 4679.73 161748.7 2148588 3735.64 -7175.58 1.32 8089.75 10521 73.2 299.8 4881.75 4706.75 161671.5 2148634 3779.84 -7254.02 0.84 8179.73 10615 73.3 299.7 4908.84 4733.84 161594.6 2148681 3824.51 -7332.17 0.15 8269.68 1 0709 73.2 299.6 4935.93 4760.93 161517.6 2148728 3869.04 -7410.4 0.15 8359.63 1 0804 73.4 298.4 4963.23 4788.23 161439.2 2148774 3913.15 -7489.98 1.23 8450.59 1 0898 73.3 297 4990.16 4815.16 161360.6 2148818 3955.01 -7569.71 1.43 8540.65 10992 73.3 296.2 5017.17 4842.17 161281.3 2148861 3995.32 -7650.22 0.82 8630.67 11086 73.4 295.8 5044.11 4869.11 161201.4 2148902 4034.8 -7731.16 0.42 8720.69 11181 72.9 295.6 5071.64 4896.64 161120.6 2148944 4074.23 -7813.09 0.56 8811.57 11274 73.5 294.3 5098.52 4923.52 161040.9 2148984 4111.79 -7893.81 1.49 8900.5 11364 74 294.4 5123.71 4948.71 160963.2 2149021 4147.41 -7972.53 0.57 8986.77 11465 73.4 294 5152.06 4977.06 160875.9 2149063 4187.15 -8060.95 0.71 9083.55 11559 73.7 294.7 5178.68 5003.68 160794.8 2149103 4224.32 -8143.08 0.78 9173.56 11 653 73.5 295.7 5205.22 5030.22 160714.2 2149143 4262.71 -8224.67 1.04 9263.66 11747 73.5 296.3 5231.91 5056.91 160634.3 2149185 4302.22 -8305.68 0.61 9353.75 11841 73.4 296.2 5258.69 5083.69 160554.6 2149227 4342.08 -8386.49 0.15 9443.84 11934 73.6 297.6 5285.1 5110.1 160476.2 2149270 4382.42 -8466.01 1.46 9533 12029 73.5 298 5312.01 5137.01 160396.8 2149314 4424.91 -8546.61 0.42 9624.11 12122 73 297.9 5338.81 5163.81 160319.3 2149358 4466.65 -8625.27 0.55 9713.16 12217 73.4 298.7 5366.27 5191.27160240.4 2149403 4509.77 -8705.35 0.91 9804.1 12311 73.4 298.4 5393.12 5218.12 160162.5 2149449 4552.82 -8784.48 0.31 9894.16 ) ) 1 2403 73.5 299.4 5419.33 5244.33 160086.4 2149493 4595.44 -8861.68 1.05 9982.33 1 2497 73.1 298.7 5446.34 5271.34 160009 2149539 4639.16 -8940.39 0.83 10072.33 1 2589 73.5 298.7 5472.78 5297.78 159932.8 2149583 4681 .48 -9017.68 0.43 10160.43 1 2684 73.3 298.4 5499.92 5324.92 159854.1 2149629 4724.99 -9097.65 0.37 10251.46 1 2779 73.2 298 5527.3 5352.3 159775.1 2149674 4767.97 -9177.82 0.42 10342.42 1 2872 73.2 298.4 5554.18 5379.18 159697.8 2149718 4810.05 -9256.29 0.41 10431.45 1 2966 73.1 298.4 5581.43 5406.43 159619.8 2149763 4852.84 -9335.42 0.11 10521.4 1 3058 73.3 299.1 5608.02 5433.02 159543.8 2149808 4895.2 -9412.64 0.76 10609.46 13152 73.5 298.8 5634.87 5459.87 159466.2 2149853 4938.8 -9491 .46 0.37 10699.51 13247 73.3 298.1 5662.01 5487.01 159387.3 2149899 4982.17 -9571.51 0.74 10790.54 13341 73.3 297.6 5689.02 5514.02 159308.9 2149943 5024.23 -9651.12 0.51 10880.57 1 3434 73.3 298.1 5715.75 5540.75 159231.3 2149987 5065.85 -9729.88 0.51 10969.65 1 3529 73 298.2 5743.29 5568.29 159152.3 2150032 5108.74 -9810.04 0.33 11060.56 1 3622 73.3 298.3 5770.24 5595.24 159075.1 2150076 5150.87 -9888.45 0.34 11149.57 1 3717 73.2 298.8 5797.62 5622.62 158996.4 2150122 5194.35 -9968.35 0.51 11240.52 13810 73.4 298 5824.35 5649.35 158919.2 2150166 5236.71 -10046.71 0.85 11329.59 1 3903 73.1 297 5851.15 5676.15 158841 .3 2150210 5277.83 -10125.7 1 .08 11418.64 1 3998 73.2 296.9 5878.69 5703.69 158761.4 2150253 5319.04 -10206.75 0.15 11509.56 1 4094 73.2 296.7 5906.43 5731.43 158680.5 2150297 5360.48 -10288.78 0.2 11601.45 1 4187 73.1 297.8 5933.39 5758.39 158602.5 2150339 5401.23 -10367.91 1.14 11690.46 14279 73.3 297.2 5959.98 5784.98 158525.5 2150382 5441.9 -10446.03 0.66 11778.53 14374 73.5 297.8 5987.12 5812.12 158446 2150426 5483.93 -10526.78 0.64 11869.57 14466 73.2 297.2 6013.49 5838.49 158368.9 2150469 5524.63 -10604.97 0.7 11957.71 1 4560 73.7 298 6040.26 5865.26 158290.2 2150513 5566.38 -10684.82 0.97 12047.82 14654 73.2 297.5 6067.04 5892.04 158211.6 2150557 5608.34 -10764.56 0.74 12137.92 14747 73.6 295.6 6093.61 5918.61 158133 2150599 5648.17 -10844.28 2 12227.03 14842 74.1 295.2 6120.03 5945.03 158051.7 2150641 5687.31 -10926.71 0.66 12318.21 14937 73.7 294.8 6146.38 5971.38 157970 2150681 5725.88 -11009.43 0.58 12409.39 1 5032 73.4 294.6 6173.28 5998.28 157888.3 2150722 5763.96 -11092.21 0.37 12500.39 1 5127 73.4 294 6200.42 6025.42 157806.4 2150761 5801.42 -11175.18 0.61 12591 .29 1 5220 73.2 295.7 6227.15 6052.15 157726.6 2150801 5838.85 -11256.01 1.76 12680.26 1 5314 73.5 296.2 6254.08 6079.08 157646.7 2150843 5878.26 -11336.99 0.6 12770.28 15406 73.3 295.7 6280.36 6105.36 157568.5 2150883 5916.84 -11416.26 0.56 12858.42 15499 73.3 295.4 6307.09 6132.09 157489.2 2150924 5955.26 -11496.63 0.31 12947.44 15594 73.8 295.5 6333.99 6158.99 157408 2150965 5994.41 -11578.9 0.54 13038.49 15688 73.9 295.3 6360.14 6185.14 157327.5 2151006 6033.14 -11660.46 0.23 13128.72 15769 73.5 295 6382.87 6207.87 157258.1 2151041 6066.18 -11730.83 0.61 13206.39 15880 73.1 295.8 6414.77 6239.77 157163.3 2151089 6111.78 -11826.87 0.78 13312.63 15974 73.4 296.1 6441.86 6266.86 157083.5 2151131 6151.17 -11907.81 0.44 13402.61 16069 73.1 297.1 6469.24 6294.24 157003.3 2151174 6191.9 -11989.15 1 .06 13493.57 16165 73.2 297.5 6497.07 6322.07 156922.8 2151218 6234.04 -12070.79 0.41 13585.44 16353 73.2 299.2 6551.41 6376.41 156766.8 2151308 6319.5 -12229.18 0.87 13765.39 16447 73.3 299.4 6578.5 6403.5 156689.5 2151354 6363.55 -12307.67 0.23 13855.36 16539 73.2 300 6605.01 6430.01 156614.2 2151400 6407.2 -12384.2 0.63 13943.4 16632 71.7 300.7 6633.05 6458.05 156538.9 2151447 6452 -12460.72 1.77 14031.96 16727 71.5 301.3 6663.04 6488.04 156462.9 2151495 6498.43 -12537.98 0.64 14121.94 16786 70.9 301 6682.05 6507.05 156415.9 2151525 6527.32 -12585.78 1.13 14177.68 16899 70.5 301.2 6719.4 6544.4 156326.1 2151583 6582.41 -12677.1 0.39 14284.13 16994 70 300.9 6751.51 6576.51 156250.8 2151631 6628.52 -12753.7 0.6 14373.37 17030 69.7 300.9 6763.91 6588.91 156222.3 2151649 6645.88 -12782.7 0.83 14407.11 17089 69.3 301.2 6784.57 6609.57 156175.7 2151679 6674.38 -12830.05 0.83 14462.27 17179 68.5 301.6 6816.97 6641.97 156105.2 2151724 6718.13 -12901.72 0.98 14546.04 17276 67.6 301.9 6853.23 6678.23 156030 2151774 6765.47 -12978.22 0.97 14635.77 17369 67.6 301.9 6888.67 6713.67 155958.3 2151821 6810.91 -13051.22 o 14721.51 17464 68.2 303 6924.41 6749.41 155885.3 2151871 6858.14 -13125.49 1.24 14809.2 17555 68.4 302.6 6958.05 6783.05 155815.5 2151918 6903.94 -13196.56 0.46 14893.4 17648 67.7 303 6992.82 6817.82 155744.3 2151967 6950.66 -13269.07 0.85 14979.29 17745 67.2 303 7030.02 6855.02 155670.5 2152018 6999.45 -13344.2 0.52 15068.47 17840 66.5 303.7 7067.36 6892.36 155598.9 2152068 7047.47 -13417.16 1 15155.37 17932 65.7 304 7104.64 6929.64 155530.3 2152116 7094.32 -13487.02 0.92 15238.98 18027 64.7 304.4 7144.49 6969.49 155460.3 2152167 7142.8 -13558.34 1.12 15324.63 18096 64.5 304.7 7174.08 6999.08 155410 2152204 7178.14 -13609.68 0.49 15386.5 0 } t ) ~ ;,' ) ) PHilliPS It œ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY v '10: Robert Crandall, Bob Swenson RECE.IVED From: Wayne Campaign 265-1505 Subject: Hansen #1 Shallow Salinities. NOV 1 5 2001 Date: November 13, 2001 _OU&GasCons.Gommission Anchorage 'This memo will discuss the evaluation of the shallow portion of the Hansen well for the purpose of estimating the salinity of the sands near the bottom of the surface casing. We have acquired continuous porosity and resistivity data from measured depths of 3530' -5140'. I have evaluated this data for Volume Shale, total porosity (PHITT), and Apparent Water Resistivity (Rwa). Rwa was calculated from the total porosity and the resistivity curve, as stated in a previous memo. Included is a log presentation of the resistivity and porosity logs plus evaluation of Vshale, a coal flag and Total Dissolved Solids calculation, highlighted in dark blue in the sands. Presented in the porosity track on the left, is the total porosity curve in red. This well is deviated 73° from vertical and there will be some problems with thin bed responses (see log, depths 4162' and 4170') where the TDS calculation will be in error. Another complication is intervals of high carbonaceous, or organic content, often in the fonn of detrital coal. These can be picked out where the neutron and density porosities are quite high yet not enough to trigger the coal flag. Several are noted at the bottom of the log. Inspection of the TDS curve in the thicker sands indicate we are at 4500 ppm salinity at the top of the interval and increases to around 6000 ppm NaCl equivalent near the bottom. There are some potential sources of error in this evaluation and I will discuss those now. Included with this memo is an addendum on the ionic concentrations in these shallow meteoric waters. They are known to contain significant bicarbonate (HC03-)' This is a large ion with reduced activity. Presence of this ion will cause our calculations to Under-estimate actual TDS. Another source of error would be the resistivity measurement itself, in this highly deviated hole. Due to anisotropy, the tool will measure a value higher than the horizontal component we need for proper modeling. This error would also cause our calculation to under estimate the actual TDS. Due to this built-in bias, actual TDS values can be expected to be higher than the 6000+ ppm we show here. A point of difference exists between the Hansen well and the original salinity work done in the Anchor Point #1. The original work from the Anchor Point #1 used sonic for porosity. An empirical algorithm (Hunt-Raymer) was used to generate porosity, and validated with core in a deeper section. Compaction is known to have an effect on the sonic. Using the algorithm from a more compacted interval, without correction, will cause porosities in the shallow sections of Anchor Point, to be slightly over estimated. Porosities that are too high would cause salinity estimates to be too low. The Hansen well was logged with the more sophisticated Neutron/Density porosity suite, giving better estimates of porosity (lower) and salinity (higher). In conclusion, all of these potential errors would bias our answers to underestimate salinity. I expect the actual salinity to be greater than 6000 ppm in the logged section of this hole. Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company Mr. Wayne Campaign November 15, 2001 Page 2 If you have questions or comments, feel free to contact me. Wayne Campaign Sr. Staff Petrophysicist cc. Swenson, Robert dd. Lloyd, William ee. Anderson, Paul Phillips Alaska, Inc. Is a Subsidiary of Phillips Petroleum Company ) Phillips Alaska, Inc ì ) ) !"IIUIPS œ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY To: Bob Swenson Wayne Campaign Salinity Addendum Sept. 5, 2001 From: Subject: Date: This letter will discuss the problems/issues of calculating salinity in the meteoric waters of the S. Alaska Tyonek sections. Logging techniques are based on salinity concentrations composed of N aCl. These waters typically contain significant Bicarbonate (HC03") ions. This is a rather large ion and has a reduced activity level compared with Na+ and cr ions used in modeling. This reduced activity is illustrated in any Schlumberger Chartbook, chart Gen-8. These effects apply to the resistivity (Rwa) method. We have log data and chemical analysis of a Rw sample from the Ninilchik #1 well (Pig. 1), drilled in 1962. The sample came from a DST measured depth of 3776' -3786' and shows a bicarbonate level of 1500 ppm out of a total 2485 ppm. Measured sample resistivity is 3.62 Q-m @ 77°P. This is nearly the exact value obtained from the logs with the Rwa technique. However, Rwa and standard methods to estimate TDS, results in a value of 1400 ppm (NaCI equivalent). Using the ionic concentrations from the sample analysis with the appropriate multipliers from chart Gen-8, gives a (NaCI equivalent) salinity of 1496 ppm, while actual TDS is 2485 ppm. At this same depth, the SP technique gives a TDS result of 3900 ppm. In summary, the presence of bicarbonate in these waters will cause the Rwa technique to underestimate actual salinity. If salinity from Rwa is greater than the 3000 ppm threshold, we can feel confident the actual number is higher. Wayne Campaign RECEIVED NOV 1 5 2001 Alaska Oil & Gas eons. ~...iIItoo Ar1chcøJ9 Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company } Mr. Wayne Campaign November 15, 2001 Page 2 ) ) L ANALYSIS OF WA ~91 OAT E or R t p ó(;{ , ':,';.;JtV)j;i;:'þ¡{~"lÌ;·7>~;.71 4".t· DATE Of SAMPLING . SAMPLED BY LABOR 'A TORY NO. ANALYST RADICALS SOOlUM CALCIUM MAGN ES I UM BARIUM STRONTIUM SULPHATE CHLORIDE CARBONATE BICARBONATE HYDROXIDE IODIDE " ,~:.,;,,'.:.', -"~~'..-::',·-.:\I~f :. "':~:~",....~~~:,,:,~,,~','~::,:,~~- "~:-~ W£~.L ! ~ o. .::#:M/J l:,'(./;l)i~w I' , COMPANV· I/Nlt'/ll 0; / F In 0 A;:/ A'~: .'::' .F' .s "", t ZON E SAMPLE SOURCE /-/CT#/ '?'7.¿~.'?7;;t;?' _REACTING VALUE REACTING VALUE EQUIVALENTS PER MILLION PERCENT .2 '/ / .. ~.2 {~,,: - ð I F 8, H~£~I~~// PARTS PER MILLION MILLIGRAMS PER LITER Na Ca Mg Sa S r S04 CI C03 HC03 OH I SILICA SI02 IRON, ALUMINA R203 TOTAL GROLLE. ALKALIS EARTH S STRONG ACIDS WEAK ACIDS Ca/EARTHS '19. I J. (J.n 3 .~' ,I 4(,,, It.. ""J.. 'i~ 7 J.'1. D I? . .!:"' 0.5 /:.19, I).. 0..9/ 3/. If'1 0, ,5').. 0.;)1-/ O.()7 ,5/;. t.. :s/? () II~{)' 6 1;'1'1<.(.2 I t, t( ;',.7.0 7. 't?3 39..33 I , ()Ô· J / if / 5.(;1.- .Îl{ I t7 1v I.{ ç; GJ...Lf CHEMICAL CHARACTER PRIMARY SALINITY SECONDARY SALINITY PRIMARY ALKALINITY SECONDARY ALKALINITY trtl. 10, IC'6,C;ç MISCELLANEOUS 7. b~ 80 RON t,/t)() HYDROGEN SULFIDE iJO.fZ EQU I VALENT .SAL T J.7G RESISTIVITY 0770F CH LOR I N I TY PPM A /;,:5 .r.'N 1"' :ç;.~ G/ G ? 6,,~ () O. M . J.-I.g-' G/G CH LOR IDE SA LI N I TV t.:? 3;", SULPHATE SALINITY 4~,61 CARBONATE/CHLORIDE c. ~ C.J..,#~r f',N (~) E. S. ,Pà'.rA'~,... F. G. þ~ ¿;/c:-A- II-Co w...l't"'r hell" II-C ,I....,il'r.?I-¿;,..,Y (~) II-C F,,~ /Ice I- ~i'~ REMARKS /,Ie -r 1111 ..7 77¿ '-J7,¿ I C""'''/~.' ¡t{ S,.I:lß PRO. 391 (I M. CD. S . 54 ) P~I"T[O IN U.S.A. I,CG)~~¥ Nat K SPECIFIC GRAVITY '15. 'I.{ p H ,~.; 7 'I TICKELL GRAPH Ca+Mg+Ba+Sr ~EACTtNG VALUE ..-\- \ C03 X HC03 OH ""--- ~ -\- -f. CltIt8r SOij ARC REPRESENTS "CONCENTRATION OF SOLI OS IN NORMAL SEA WATER" . SIGN EO: II': k)/~ - - L ~/,rdi'f''/ r! rc:j?¿: Fig. 1. Lab analysis for Ninilchik water sample. Note high Bicarbonate and lab measured Rw. Phillips Alaska, Inc. Is a Subsidiary of Phillips Petroleum Company ) Mr. Wayne Campaign November 15, 2001 Page 3 ') ) NINILCHIK #1 ....... . .~..... . . . . .. S !I, l__ ¡ ...... , . . . . . .., ..". . . . . . . . . -100 11/I'.1 () TDSS_1 o K""II ILD_ES S 1 10 DEPTH '7' - - - ~;üII- - - -'00 FEET \ "":1 S N fS S 1 DTX_1 --------------- ON..II 100 1SO usn so it'" j- , ,. ,4_ ': ¡i c'( . II ;..," i.' ii ':{~" I II ~rfŸ. --¡-þ ( , ¡::\. , , '.: i.}~. ~,"--.. . Ii ~i . · : I.... i ' : ,~ - ~ '1' ;-- ¡:~I i .:~).. . --"-:·+~l C),ST ¡¡¡¡Ii I'll ¡: ; i :-I~t : : , II \' !., I I';'--/- : ¡i _~: 3100 .. ¡ - _ ':- ~--t--1- ¡~...,¡ ... ... - I , ,... '"":, ,.- ¡~I ...1 _ ~ ....... ; _1-= . .. ,_:-- ~ ... -t- 4..~- ~- I ~~ _l-I '" ,. .,. , 1L.B!L.- .:f .... ~ ~(-, ~' 1 f>"'¡;'i. '..f ,': t , I ,. Ii. I " . ...__ 'I_L ~~ ~~_,I '_~I ~i_ I " I 11 } I' ~ ... ,......~ ,,, I ... I þ- .... ! ~I--'" I..~ 3800 ~ \ ~ ,'''''"'',.(- ~ ",.¡ ~ 'ž· .:... : l-- C~ ~ -, 3900 Fig.2 Logs from Ninilchik #1 with DST interval highlighted. Average sonic value used was 115 µs/ft. and Rt of 23 Q-m to give a Rwa value of 3.64 Q-m @ 75<>P. Lab measured Rw (Fig. 1) was 3.62 Q-m @ 77<>P. Apparent TDS in track 1 is colored dark blue in the sands (defined by SP) and gray elsewhere. Phillips Alaska, Inc. Is a Subsidiary of Phillips Petroleum Company \.> ) ~HI~~'\ PHilliPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY ) Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 November 6,2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 w. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Hansen #1 Application for Sundry Approval (APD 201-157) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to change the surface casing depth as was previously proposed in the Permit to Drill for the Hansen #1 well. If you have any questions regarding this matter, please contact me at 263-4603 or Bill Lloyd at 265- 6531. Sincerely, ~~íi:r~ Exploration Team Leader PAl Drilling PMlWUskad RECEIVED NOV 0 ,~.; 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL 1··~ , l' ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION } JM"' 11/ tItIo' k\ \ ~ lit {~ {\Vú// Ú" ~ -,. 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Description summary of proposal _ Detailed operations program _ BOP sketch I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _ 14. Estimated date for commencing operation 15. Status of well classification as: November 5, 2001 161jlf r~osal was ver~all approved )'::.'7YYl. \ \ {S-a \ ame of appfoW' Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ?~YV¡r A~ -'!-:.; ~ Paul Mazzolini r.A'1fõ' ~'" Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. 0; Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2148' FSL, 1527' FEL, Sec. 2, T4S, R15W, SM At top of productive interval 1750' FNL, 1641' FWL, Sec. 33, T3S, R15W, SM At effective depth At total depth 886' FNL, 55' FEL, Sec. 32, T3S, R15W, SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Surface Production Length 93' 698' 5073' Size 30" 20" 13.375" Perforation depth: measured No perforations true vertical No Perforations Tubing (size, grade, and measured depth No tubing run Packers & SSSV (type & measured depth) No packers, No SSSV 13. Attachments Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service (as proposed) (as proposed) feet Plugs (measured) feet feet feet Cemented Junk (measured) Driven 803 sx Class G as proposed Oil Title: Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- Original Sìgned By Cammy Oachs'i ARproved by .order 2Lthe C<?m!TIission Form 10-403 Rev 06/15/88 · ORIGINAL Re-enter suspended well _ Time extension Stimulate Variance Per10rate 6. Datum elevation (OF or KB feet) 163' RKB feet 7. Unit or Property name Other _X Change surface depth Cosmopolitan Project 8. Well number Hansen #1 9. Permit number / approval number 201-157 10. API number 50-231-20010-00 11. Field / Pool Exploration / Measured Depth 93' 698' 5073' True vertical Depth 93' 698' 3310' RECEIVED NOV 0 8 2001 Alaska Oil & Gas Cons. Commission Anchorage Gas Suspended - 2 Quesljons? Call WIlHam Lloyd 265-6531 IfIß- r 11/0(,. '0 I Date II Prepared by Sharon A lis ur;Drake ("\O~Cc Approval no. l J 1 '-~O - 31, /;)~ Commissioner Date SUBMIT IN TRIPLICATE Re:. Chcitige to surface casing setting depth - Hansen #1 " ) ) Subject: Re: Change to suñace casing setting depth · Hansen #1 Date: Mon, 05 Nov 2001 17:02:04 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: William B Lloyd <wlloyd@ppco.com> CC: bob_crandall@admin.state.ak.us, Sharon Allsup-Drake <sallsup@ppco.com>, Robert F Swenson <rswenson@ppco.com> Bill, Thanks for bringing over the information. You are correct that the information you have developed does indicate that the salinities in the strata you have penetrated does exceed 3000 ppm. On that basis and finding a suitable casing seat as you note, you have approval to set the surface casing shallower than was approved in your permit approval. Although this reply does give you approval to proceed with this change, a sundry notice will be required as a formal acknowledgment of the change from what was originally permitted. Good luck with the operations. Tom Maunder, PE Sr. Petroleum Engineer AOGCC William B Lloyd wrote: > Tom and Bob, > > Thank you for meeting with Wayne and I regarding surface water salinities > on Hansen #1. Per our discussion, we understand we have demonstrated via > L WO logs that the sands that have been encountered at the existing depth of > 5073' MD/3310' TVD are sufficiently above the 3000 ppm TOS·threshold to > allow for setting of our 13-3/8" surface casing. At this point we will > continue to drill to such a depth as to identify a suitable casing shoe to > insure a high FIT at the 13-3/8" casing shoe. I will notify you as to what > depth we choose however at this time I do not anticipate we will need to > drill beyond 5500' MD. > > According to AOGCC regulations, a Sundry Notice for this variance to the > wellplan is not required. > > If you have any questions, please call. Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1of2 11/8/01 12:36 PM Rê: Di.verter test - failed sensors ) l ¡ Subject: Re: Diverter test - failed sensors Date: Mon, 29 Oct 2001 14:33:24 -0900 From: "William B Lloyd" <wlloyd@ppco.com> To: Tom_Maunder@admin.state.ak.us Here's the answer... __ù_ Forwarded by William B Lloyd/PPCO on 10/29/01 02:33 PM ----- Nabors 273E Company Man 10/29/01 02:32 PM To: William B Lloyd/PPCO cc: Subject: Re: Diverter test - failed sensors(Document link: William B Lloyd) Bill, An instrument tech and parts came down from Anchorage yesterday afternoon. 1 sensor was calibrated and the other one was replaced. 80th sensors were tested and functioning OK. Thanks Donnie Lutrick William 8 Lloyd 10/29/01 02:22 PM To: Nabors 273E Company Man/PPCO@Phillips cc: Subject: Diverter test - failed sensors Donnie/Guy, Tom Maunder just called and told me that John Spaulding noted 2 failed sensors during the diverter test that needed to be repaired prior to commencing drilling operations. Tom needs verification that this has been completed. Please let me know what was done to repair. Thanks 1 of 1 10/29/01 2:33 PM MEMORANDUM ) State \.II' ~laSka Alaska Oil and Gas Conservation Commission DATE: October 28,2001 ¿- TO: Camille O. Taylor 00\ Commissioner b THRU: Tom Maunder ~01'flì~ò \. P.I. Supervisor I ~ ~ à~" Oc..; SUBJECT: Diverter Function Test Nabors New Rig # d \ ~ Phillips Petroleum Hansen # 1 201.;157 Exploration FROM: John H. Spaulding Petroleum Inspector Operator Rep.: Donnv Lutrick Contractor Rep.: Allen Lunda MISC. INSPECTIONS: Location Gen.: ok Well Sign: Housekeeping: ok (Gen.) Drlg. Rig: Reserve Pit: ok Flare Pit: NON- CONFIDENTIAL Op. phone: 263-3140 Rig phone: ok ok nla Op. E-Mail: Rig E-Mail: ACCUMULATOR SYSTEM: P/F Systems Pressure: 3000 psig P Pressure After Closure: 1325 psig P 200 psi Recharge Time: 1:10 min:sec P FullRecharge Time: 4:47 min:sec P Nitrogen Bottles: 3 ~ 2150 AVG. MUD SYSTEM INSPECTION: DIVERTER SYSTEM INSPECTION: Light Alarm Diverter Size: 30" in. Trip Tank: ok ok Divert Valve(s) Full Opening: yes Mud Pits: ok ok Valve(s) Auto & Simultaneous: yes Flow Monitor: ok ok Vent Line(s) Size: 16 in. Vent Line(s) Length: 130 ft. GAS DETECTORS: Line(s) Bifurcated: nla Light Alarm Line(s) Down Wind: yes Methane P*** P*** Line(s) Anchored: yes H2S: P*** P*** Turns Targeted I Long Radius: n/a .. 116" X 130" vent line pumps and motors ~ \ Iwinrl rlirp.r.tinn Pit area sub base 30,,0 annular P Test's Details I traveled to Phmips Petroleum's Hansen # 1 well to witness the diverter function test on Nabors rig (new rig #)273. The function test went well with the knife valve opening well ahead of the 30" annular's closing. I found the vent line to be well constructed with ample length (130'). nabors has added a 2nd electric accumulator pump. this has speeded up the recovery considerably. While witnessing the gas detector tests - it was discovered that 2 detectors, 1 methane and 1 H2S dectors were found to be faulty. I informed Donny Lutrick PAl rep. that he would no tbe able to commence drilling operations until these 2 items were repaired and tested and the AOGCC notified in writing. I Pad entrance Total Test Time: ~ ~ Number of failures: ~ Attatchments: !!2!!! diverter nabors 273 hansen 1028 01js.xls I}" ~~~~E : F ~:!Æ~~~!Æ I ALASKA OIL AlQ) GAS / CONSERVATION COMMISSION / Paul Mazzolini Exploration Drilling Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 .~ ) TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Hansen No. 1 Phillips Alaska, Inc. Permit No: 201-157 Sur. Loc. 2331' FSL & 1493' FEL, Sec. 2, T4S, R15W Btmhole Loc. 886' FNL & 55' FEL, Sec.32, T3S, R15W Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtajning a well,Jemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Ço~is,sion for approval on . ./,' fonn 10-403 prior to the start of disposal operations A I c¿~ ,;,t ,~~..~(>C,::,~iJ'~1' .~,;..(,:.,i¡/ t I:., '> { (: i / r,) 41 J b:, ¡' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ ~r9<-Jv;,L: k..ú0 Cammy Oeehsli Tayl~~ D·· Chair BY ORDER OF THE COMMISSION DATED this 21st day of September, 2001 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~ þlL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work Drill _X_ Redrill 1 b. Type of well Exploratory _X_ Stratigraphic Test _ Re-Entry _ Deepen _ Service _ Development Gas _ Single Zone _ 2. Name of Operator: 5. Datum Elevation (OF or KB) Phillips Alaska, Inc. 163 feet 3. Address: 6. Property Designation P. O. Box 100360 Anchorage AK 99510-0360 ADL- 384403 4. Location of well at surface: 7. Unit or Property Name 2331' FSL & 1493' FEL Sec2-T4S-R15W, Kenai Borough Cosmopolitan Project At top of productive interval: 8. Well Number 1750' FNL & 1641' FWL Sec 33-T3S-R15W, Kenai Borough Hansen No. 1 At total depth: 9. Approximate spud date 886' FNL & 55' FEL See 32-T3S-R15W, Kenai Borough 'ðQ.Lj,,~ ~ \\) h- c:> \ 12.Distance to nearest 13. Distance to nearest well 14. No. of acres in property property line app rox. 300' feet 16. To be completed for deviated wells Kickoffdepth: 600 ft Maximum hole angle 74 degrees Casing program 2.5 miles 2560 17. Anticipated pressure Maximum surface 2500 Setting Depth ,I ) JM;~ ÁI\/ q;lzó1ð' a7--.-, ~}.. '1 V J (j ~.Fç.A / Development Oil _ Multiple Zone _ 10. Field and Pool Exploratory 11. Type Bond (SEE 20 AAC 25,025) Statewide Number 59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 18,898 MD feet 7,263 TVD psig (SEE 20 AAC 25,035 (e)(2)) At total depth (TVD) psig BHP 3172 size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 30" 0.5" wall 5L-B 5-60 Dril-Qui~ 145' -170' Surface 25 135' 135' Driven 24" 20" 0.5" wall 5LX-56 5-60 Dril-Qui~ 700' 30' 30' 700' 700' 740 sx 'G' 17-1/2" 1 3-3/8" 72 L-80 Prem 6600' 30' 30' 7046' 3863' 4350 sx 12.5# "G", Tailed w/ 6400 sx 15.8 # "G" 12-1/4" 9-518" 53.5/47 L-80 Prem 17000 30' 30' 17000' 6718' 140 sx 12.6# "G", Tailed with 240 sx 15.8 # "G" 8-1/2" 7" Liner 26 L-80 BTC-Mod 1800' 16761 ' 6649' 1 8898' 7263' 450 sx 15.8# Class "G" + Additives 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical measured true vertical Length Size feet feet feet feet Cemented Driven Yes Yes Yes Yes Effective depth: Casing Plugs (measured) Junk (measured) Measured depth True Vertical depth IT~C~/ /¡ JU 'l:D A/ask. '/... 2 6 , a 01/& <00/ Gasc Anch Ons. Co orage 'Il7/J]lss . IOf) Structural Conductor Surface Intermediate Prod. Liner Perforation depth: measured true vertical NOTE: This Application for Permit includes a request to use the 13 3/8" x 9 5/8" casing annulus for injection of the drilled cuttings, storage cell fluids and excess drilling fluids. All necessary documentation will be provided following 9-5/8" casing setting. 20. Attachments Filing fee _X_ Property plat _X_ BOP sketch _X_ Diverter Sketch _X_ Drilling program _X_ Drilling fluid program _X_Time vs depth plot _X_ Refraction analysis _ Seabed report __ 20 AAC 25.050 requirements (Directional Program) 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Contact Bill LIoyd@ 265-6531 Signed~<:" r¿ fY/~Title "'p."'" O,iII,",T"m L"'" Date 07/2.0 /01 Commission Use Only Permit N~mber API ~umber _ .... Approval D~e . 2D!'- ¡Ç-7 50-~81-2C()/O -(.2) ..rbl/o, Conditions of Approval: Samples required --X. Yes _ No Mud log required X. Yes Hydrogen sulfide measures _ Yes L No Directional survey required L Yes Required working pressure for BOPE 2M 3M 5M 10M 15M Other: Approved by Form 1 0-401 Rev. 12-1-85 Original ~irJned ~ Cammy Oechsli See cover letter for other requirements No No ~ooC) ~\ ~\"'\~~..V\.. \SCJ~ \-~ Commissioner by order of the commission Date q/~ /"1 o HI"Gi"¡tVAL W~I 1 I U·,'" OI'-vV nL.."n\.J1 ,... '-" """"". .1" ;. ."'_ ."'__...._....__ __,r "'_ - -. - - - . - -- >- ~ .I Phil~s Alaska, Inc. 700 G Street, Anchorage, AK 99501 ....... ~.. ,........,... 1'.......,.,......... ,.. '.u _ __ _:..n FAX 'Date:' , ... ., ~L?- ~..I OJ _~.u.. _....... . Number of pageß including clwer sheet: -=~- LLlr~----~--\ _. ._' To: ~M ._A1~_~~~p-" __ .n. ~ ..... . From; --'~JÙ~ u¿¡1 <l .. W~I.'~...GrO~p. __ ___" . _·,"'.r· _ __ .__. _._ r . ...... '.. -. ., . .. -& -~....... .--- ... .-. -. -~ ..-.... ~ ~ ..--.. ....~._. .. ..... . ....-.....-.- - ....-- . - .'U_ ..- '-'.-'..'JI .--.,---...,.-...-... .. ... ~. ..... ... ... . ... ~....n~~_...~~_.._.-.: Phono: -.-----.. - .__._-.._~.._. F~~.p~9I!e,~ .. 2_Zk,_-:_~?- . _.r .'.__..u.· _.._ Phone: - .,......- ..,..- -.... '--' - .. u........._~_- n_'_~:~6~~~-"· Pax. phone: cc: ...&. \ . .. . _, ._ ____...._ 'u......_~ n.." ........ l.ocation: ATO-1529 ,..... .... .."... . ",._...... ......T-~ _.:..~ ........ ._.\':....~ -- REMARKS; 0 Urgent 0 For your review 0 Reply ASAP ~~~ o Plc~ comment ......\ ..... ......... ............._ ................ . ... ..,__u. , .. ,..,--.-'-'" ..'----........-....... ---. .- -.. .. -- - - - - --- - - - --- -~ Mon··Weld Centralizers . TANDEM RISETM BOW CENTRALIZERS This special design increases the ratio of restoring force to moving force. It has the ability 10 withstand high lateral loads encountered in horizontal holes. The non- weld design increasos its rlbility to withstand compressive loading while running in the weUbore. It is available for close tolerance applications and can be installed over casing couplings and stop collars. Ils benefits include: · ßetter standoff for increased mud removal · Reduced drag while running pipe · Reduced wall sticking for easier pipe movement · Increased conlact area ror less bow penetration inlo the formation · Complete mud removal while cementing ! -: . TR 1 r~ ... '---=-z--¡.. ,~- ~ L ... ... ...- .. .... .... - -------- ..-...J TR 2 ~_--:=-~~---------=.-.:-_-~ .,..----~ ".,..,...,.--~ TR 3 ~ ¡. ~ . ~~-~-~- TR4 .__ ./~~J>,_~-~ . I ¡, I' i, Tandem Rise Bow Profiles ;:~:~~~-[~~7;':_l~~!i!~\~~i'I' Tn1 .171 4.35 ,000 20.32 14 I/~" 356.e~ TR2 .171 4.35 1.171 29.74 14 '/" 358.8 . '._~__-'''1ooiP''''''' TR3 -.171 4.35 1.421 36,09 14 '/8 . 358.8 -........ '\" "-:-"_."';.I.""I="""-¡,.y- TR4 .171 4.35 2.171 55.14 141fn 358.6 *Baasd on V~" clearance for coupling NOTE: 1} All bows 1 '/~ N (38.1 mm) wide NON-WELD STRAIGHT CENTRALIZERS - TUBING Tubing centralizers can be effective in tubingless oom- pletions, for guiding and stabbing tubing into downhole equipment or in reducing frictional drag in deviated holes. They can· al$p be used to center wireline tools, to protect control lines and cables, or to prevent wear on tubing and casing due to to thermal expansion and contraction. For optimum tubing concentricity, Weatherford recommends the use of positive tubing centralizers inside casing. Non...Weld Straight Centrall2ers - Tubing ~r!iiI~f1~~Æ{-i,··.:·'I~.l~B;~~i~J~I . STIr 5'1. 130 3'10 86 2% STili 51/~ 140 3'1'Il 89 STTII! 7'/.. 184 3'12 89 STTIV 81ft 216 3'/~ 89 STìI fiGfa 143 37/0 98 21/0 STTII 6 153 4 102 STIli! 7Y4 197 4 102 STTIV 9 229 4 102 STII 6'h 169 4'h 114 3f/~ ; STrll 6~/ð 189 4"/e 117 STIli! 8~/. 213 4'>fg 117 STIIV ItJYe 245 .. -.-1~~ "When bows are completely compressed. these figures represent the centralizer's largast rigid diameter presented by the bow. the hinge or any other part. NOT[: STI and STI! centralizer~ should not be Installed over any casing coller or stop collar. 6 ~t:.I~ 1 [1;. l\I\.LV l\Ll\~f\1i 1 J '4L - ¿ù- ~ , ù' ~ Ul m '1 nu nLùVUH.'-'L IJL- -- '-" Weatherford Cementing Products t.I'-', "'-'1'-1 '_"'6-..oI~1' _-. __ -. We Provide the Oil & Gas Industry with ;-------- PRE-DEFINED FIN LOAD RESISTANCE SpiraGlider fin design resists high sideloads, yet are engineered to intention- ally yield at predetermined sideforce under stuck-pipe conditions. SPIRAGLIDERTM HIGHLY DEVIATED AND HORIZONTAL WELL CENTRALIZER SYSTEM SHAPED TO MINIMIZE RUNNING RESISTANCE Both spiral and straight fin designs minimize drag forces while running pipe. The fins glide smoothly on the low side of horizontal , I boreholes. STEEL CONSTRUCTION The SpiraGlider system is made of steel. giving it a toughnass advantage over other materials and alloys. 1.0" SMOOTH SURFACE Wide symmetrical fins are smoothly beveled on both ends to have lower coeffi- cient of friction and to ease casing movement in either direction. Typical Average Coefficient of Frlctlonu ---_._._--~....... 0.12 "'*Valid for waterlben- c: 0.10 tonite. water/chalk and: .2 oil base mud, accord· Õ 't: 0.08 Ing to a study by the LL 'õ Institute of Tribology, ë 0.06 Technical University of (l) Clausthal, Germany '0 ~ 0.04 0 0 0.02 0.00 2 '_--·Zinc· .. st~~I·l OPTIMIZED HYDRODY~ NAMICS AND FlOW"BV AREA Hydrodynamic shape of spiral fins allows optimal mud displacement and minimal pressure drop across centralizer. Induced vortex flows enable $uperi~ or mud removal. UNIQUE STOP COLLARS Provide protection for the centralizer's leadíng edge and performs as a posi- tioning device. Tf.1e Weatherford SpiraGlider centralizers are the . newest irU1ovations in R broad offering of cementation products. They were designed specifically for highly devi~ ated or horizontal welts and are ídeal for use with linêr hangers. The SplraGlider system consists of a STEEL centralizer and two asymmetricallywbeveled stop collars. The Spir~Glîder centralizer's unique design features allow them ·to run in restricted holes while yielding reduced wear and a low coefficient of friction for miminal . drag. Thëy promote optimal mud displacement during cementation, utilizing fins that craate a vortêX motion for superior mud removal. The SpiraGlider construction is tough and gives maximum standoff and wear resistance. I ) )I PHILLIPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY as Cons. Com'T1ission Anchorage "- P. O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 19, 2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue # 100 Anchorage, AK 99501-3539 Re: Application for Permit to Drill: Hansen #1 (Exploratory Test) Surface Location: 2331' FSL, 1493' FEL, Sec. 2, T4S-R15W Target Location: 1750' FNL, 1641' FWL, Sec. 33, T3S-R15W Bottom Hole Location: 886' FNL, 55' FEL, See. 32, T3S-R15W Dear Commissioner Seamount, PHILLIPS Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well from the referenced location near Anchor Point, Alaska. The well is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail the following: Drive a 30" structural casing string to rv145' - 170' MD (pre-rig - driven to land below base of bluff). Drill a 24" hole to 700' and setting a 20" conductor string. Directionally drill a 13-1/2" (pilot) surface hole with a fresh water LSND system to a depth of rv 7046' MD / tv3863' TVD, open to 17-1/2", and run 13-3/8" surface casing. Swap drilling fluid to an invert emulsion oil base and directionally drill a 12-1/4" intermediate wellbore to tv16,911' MD / rv6693' TVD and run 9-5/8" intermediate casing. The purpose of the intermediate casing is to put potentially troublesome coal intervals behind pipe thereby allowing a reduction in fluid density for the reservoir interval and avoiding potential problems to TD. . Drill an 8-1/2" production hole with invert emulsion oil mud to TD and run a 7" liner. The conductor and surface casing strings will be cemented to surface. The intermediate string will be cemented (at a minimum) per 20 MC 25.030(d)(5). All cuttings and associated fluids will be contained within two surface pits until such time as annular injection can commence down the 13-3/8" x 9-5/8" annulus, per 20 MC 25.080. Upon reaching TD, evaluation and testing plans will be formulated and the appropriate notice(s) to the AOGCC will be provided. Please find attached information as required by 20 MC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 MC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). ) ) 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 MC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Nabors 273) as required by 20 AAC 25.035 (a) (1) and (b) 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore schematic is also attached visually depicting the proposed well and completion design. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a) 8) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig. Complete mudlogging operations such as type log generation and sample catching are planned. The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 AAC 25.071) Robert Swenson, Geologist 265-6808 The anticipated spud date for this well is September 15, 2001. If you have any questions or require further information, please contact Bill Lloyd at (907) 265-6531 or Paul Mazzolini at (907) 26 -4603 RECEIVED JUL 2 3 2001 cc: CONFIDENTIAL - Hansen #1 Well File Paul Mazzolini ATO-1570 Andy Bond ATO-1310 Robert Swenson ATO-1368 Alaska Oil & Gas Cons. Commission Anchorage ) ) Phillips Alaska, Inc. Drill and Case Plan for Hansen #1 RECEIVED JUL 2 3 2001 General Procedure: Alaska Oil & Gas Cons. Commission Anchorage 1. MIRU Nabors 273 over pre-installed 30" structural casing set at tv135' BGL. Weld landing ring on casing. 2. Install 30" diverter with 16" diverter line per attached diagram, and function test same. Notify AOGCC at least 24 hours prior to test. 3. Spud well and drill 13-1/2" pilot hole with FW spud mud to the conductor casing point at 700' MD / 700' 1VD (first competent shale below 600'). Open hole to 24" to TD. 4. Run 20" conductor casing and cement to surface with 795 sacks Class G. Do a top job if necessary, notifying PAl and AOGCC prior to commencing top job. 5. Lift diverter, install 30" 500 psi x 20-3/4" 3000 psi starting head with 20-3/4" x 30" 3M starting spool. Re-install diverter and function/pressure test same. Notify AOGCC at least 24 hours prior to test. 6. Drill out 20" shoe and drill 13-1/2" pilot surface hole to ±7046' MD / ±3863' 1VD. Open hole to 17- 1/2". 7. Run 13-3/8" surface casing to TD and cement to surface with 4990 sacks of Class G cement. Displace cement with invert emulsion oil based drilling fluid. 8. ND Diverter and NU 20-3/4" 3M x 13-5/8" 5M spool and 5M psi BOP stack. Test to 5M psi for 30 minutes per PAl Drilling Policy. Notify AOGCC at least 24 hours prior to test. (NOTE: MASP for the well is anticipated to be 2500 psi as indicated in this application. In addition, shallow hazard documentation and offset pressure information also indicates that reservoir pressures are at normal gradient. Although PAl will install and test a 5M psi x 4 preventer stack configuration, based upon the MASP we request an exception to 20 AAC 25.035( e)(l)(B)(i) and instead, request compliance to 20 AAC 25.035( e)(l)(A)(i). This exception would allow one ram for the drill pipe OD am. r.am for the liner OD in the 3 ram stack when running 7" liner.) ~~+c.. ~ \~ . <?J'Y{ q { 9. PU 12-1/4" bit, BHA and LWD/MWD logging tools and RIH. Pressure test casin~to 2500 psi. Drill 20' of new hole and perform FIT/LOT to 13.0 ppg. Fax results to town. 10. Run cement bond log evaluation tool across surface casing. 11. Drill 12-1/4" wellbore to 16,911' MD / 6693' 1VD with invert emulsion oil mud. 12. Run and cement 9 5/8" 47# & 53.5# L80 SL BOSS casing string to surface. Cement with 420 sacks Class G cement. (Note: 9-5/8" string is to isolate potentially troublesome coals prior to drilling into the reservoir.) 13. Make up 8 '/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 2500 psi for 30 minutes · Record results and fax to town 14. Drill float equipment and approximately 20' of new hole · Perform LOT / FIT for to either 11.0 ppg or the modeled ECD, whichever is highest. · Record results and fax to town 15. Drill 8V2" well bore to ±18900' MD/±7263' 1VD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. · Condition hole and mud for e-line logs. 16. Log 8-1/2" well bore as necessary. (Due to hole angle, logs may be DPC) 17. If productive, run and cement 7" 26# L80 Buttress Liner ORiuiiJA- ') ) Phillips Alaska, Inc. 18. If productive make a cleanout run and run and land 3 112" tubing configured for jet pump completion. Completion program to be provided via Sundry application. 19. Nipple down BOP's. Install production tree and pressure test same to 5000 psi. 20. Secure well, release rig. DRilliNG FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRilliNG AREA RISKS Hansen #1 Drillinq Fluid Properties: I Spud to surface Intermediate Hole I Production Hole I casing point (Intermediate shoe to TD) Fluid Type r LSND - Spud Invert Emulsion OB Invert Emulsion OB Density r 9.0 - 9.5 ppg 9.8 - 10.6 ppg 8.9 - 9.2 ppg PV I 16 - 26 23 - 27 23 - 27 YP I 25 - 35 21 - 25 19 - 23 Funnel Vis I 50 - 100 O/W Ratio: 80:20 O/W Ratio: 80:20 or 90:10 Initial Gel I 10 - 20 ES: 400 - 500 ES: 400 - 500 10 Minute Gel I 15 - 40 CL-: 280,000 CL-: 280,000 API Filtrate I 7 - 15 HTHP: 5 - 7 HTHP: 4 - 6 pH I 9.5 - 10 % Solids I ± 10% < 5% LGS < 5% Drilling Fluid System: 3 - Triple Derrick Shale Shakers Desander / Desilter / Mud Cleaner Centrifuge Swaco Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Surface Pressure and Casinq Desiqn: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Pore Casing Casing Setting Fracture Pressure Pore Size Depth Gradient Gradient Pressure MASP Drilling 20" 700' MD / 700' 1VD 11.0 ppg 8.4 ppg 306 N/A 13- 3/8" 7047' MD / 3863' 1VD 15.0 ppg 8.4 ppg 1690 323 psi 9-5/8" 16911' MD / 6693' 1VD 16.0 ppg 8.4 ppg 2923 2500 psi 7" 18898' MD / 7263' 1VD 16.0 ppg 8.4 ppg 3172 2436 psi 0. ~, 'G,Nt ~ ) ) Phillips Alaska, Inc. Expected Maximum Mud Weights: 17-1/2"" surface hole to 7047' MD 1 3863' TVD: 9.4 ppg 12-1/4" intermediate hole to 16911' MD 1 6693' TVD: 10.6 ppg (for stabilization of shales and coals) 8-1/2" Production Hole to 18898' MD 1 7263' TVD: 9.2 ppg Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.0 x 0.052) - 0.11] x 700 = 323 psi OR MASP = FPP - (0.11 x D) = 1687 - (0.11 x 700) = 1610 psi 2. Drilling below 13-3/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(15 x 0.052) - 0.11] x 3863 MASP = 2588 psi OR MASP = FPP - (0.11 x D) = 2923 - (0.11 x 3863) = 2500 psi 3. Drilling below 9-5/8" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(16.0 x 0.052) - 0.11] x 6693 MASP = 4832 psi OR MASP = FPP - (0.11 x D) = 3172 - (0.11 x 6693) = 2436 psi O:¡"GINJL ) ) Phillips Alaska, Inc. Casing Design Performance Properties Internal Tensile Strength Size Weight Grade Connection Yield Colla pse 30" 3// wall 5L-B S-60 Structural Casing Joint Body 20" V2" wall 5LX-56 S-60 Conductor Casing 13- 3/8" 72 ppf L-80 SL -Boss 5380 psi 2670 1973 M 1661 M 9-5/8" 47 ppf L-80 SL -Boss 6870 psi 4750 1289 M 1086 M 9-5/8" 53.5 ppf L-80 SL-Boss 7930 psi 6620 1476 M 1244 M 7" 26 ppf L-80 BTC-M 7240 psi 5410 667 M 519 M Casing Setting Depth Rational: 30" @ 145' - 170' MD RKB Structural casing to provide sufficient anchor for conductor string (Set below bluff). 20" @ 700' MD RKB Conductor casing to provide sufficient anchor for surface string, for fracture gradient for diverter system, and isolation of fresh water zones. 13-3/8" @ 7046' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling intermediate well bore. 9-5/8" @ 16911' MD RKB Intermediate casing is set strictly to provide isolation of potentially troublesome coals that may need higher mud weight for stability than would be necessary for the reservoir pore pressure. 7" @ 18898' MD RKB Production casing of sufficient diameter for maximum perforation penetration. String design allows for contingency string in the event hole trouble in the intermediate interval requires an additional casing string. Well Proximity Risks: None DrillinQ Area Risks: Shallow Hazards: Refer to attached "Pre-Drill Seismic Pore Pressure Prediction for Hansen #1" dated June 24, 2001. Drilling Risks: Drilling risks in the Hansen #1 area are surface interval clays and gravels, intermediate interval sloughing coals, and hole cleaning challenges associated with ERD drilling. Areas of shallow gas accumulations within coal intervals are not anticipated in this part of the inlet and have not been seen in either of the offset wells (Starichkiof State #1 and Starichkof State Unit #1). Surface clay problems will be counteracted with fluid chemistry and rheology. Coal stability in the intermediate interval will be controlled while drilling with fluid chemistry, rheology, hydraulics and fluid density. Annular Pumping Operations: See attached letter dated June 11, 2001 O~,'GeNA~ ) ) Phillips Alaska, Inc. Geology: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION DEPTH (55) UNCERTAINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE, psi Beluga Tyonek Lower Tyonek Starichkof Sands Hemlock 150' 1730' 4640' 6530' 6810' 50' 100' 75' 50' 50' Possible coal gas Possible oil/gas Expected Oil Bearing Possible oil bearing 827 2098 2923 3041 Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR/Res. 12-1/4" Intermediate: LWD: GR/Resistivity/PWD 8-1/2" production Interval LWD: GR/Res/PWD Wireline: GR/Res/*FDC-CNL/*Dipole Sonic/CMR/MDT (*denotes possible log run) II. Coring None III. Mudlogging Mudlogging service should be in operation from the base of the surface casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to 4500' subsea Thirty-foot (30') wet and dry samples will be collected from 4500' subsea to well TD and ten-foot (10') wet and dry samples, or continuous, collected across the Starichkof sand intervals. IV. Flow Testing Flow testing and pressure build-up tests, if warranted, will be used to determine formation properties and estimate the commerciality of this exploratory well. Flow testing for any particular interval will consist of an initial unstimulated flow period followed by an appropriate pressure build-up. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or reinjected into the formation following completion of the flow testing operations. Based upon pressure and flow characteristics during the unstimulated flow period, a reservoir stimulation may be performed in the form of an acid or frac treatment followed by a second flow test and pressure build-up. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. Ci/GINÞL ) ) Phillips Alaska, Inc. Hansen #1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ,1,,7"',,'!1~,~,~" Hole l:t,~.:"~,,lª" Casina Interval Event Clay Balling Risk Level Medium Abnormal Pressure in Surface Formations Directional Control Low Medium Lost Circulation Low Mitiqation Strateqy Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Diverter drills, increased mud weight BHA design, on-sight geologic review, avoid "drilling the line" Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, controlled running speeds. 12-'J.14" Hole I 9~,51.ß" Casina Interval Event Lost circulation Risk Level Low Hole swabbing on trips Low Sloughing Coals, Tight Hole Medium Abnormal Reservoir Pressure Hydrogen Sulfide gas Low Low Mitiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre- planned LCM pills, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Increased mud density and fluid composition according to plan, controlled trip speeds, ECD monitoring, optimized hydraulics for hole cleaning, contingency for additional casing string. Well control drills, increased mud weight, contingencies for top set casing string. H2S drills, detection systems, alarms, standard well control practices, mud scavengers Ú h I Co IVh,- ) ) Phillips Alaska, Inc. .$-1/2" Hole I 7" Casina Interval Event Lost circulation Hole swabbing on trips Directional Control Abnormal Reservoir Pressure Hyd rogen Su Ifide gas Risk Level Low Low Low Low Low Mitigation Strate~y Fluid density according to plan, reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BHA design, on-sight qeoloqic review. Well control drills, increased mud weight, contingencies for top set casing string. H2S drills, detection systems, alarms, standard well control practices, mud scavengers OR¡l:invA: C :::t:J --- ~""-.. ~ ~~-; ~. --..". . c=.' ~. r--~, "- "'- "- '\ \ I ') ~o~ / ~~t? c:>vf?) J I ) ~~~'i-' / / / ~ / / / f. I ( I f I / ) / / =/ / / / I ~I / ~ il I ( 1505.9' l!s/ / " . I ~I I I PROPOSED ASP ZONE 4 NAD 27 \ SURFACE N= 2144779.8 I I I LOCA TION ) \ E= 168876.9 I \ GND. EL.= 133' i ( JI \ . ) NE 1/4 il I ð I SE 1/4 ß/ LO T 4 ) S2 / If 28.828 ACRES I / ( I \ I I \ ) / / I \ I r I ~ \( "":I I \ I \ I b I ~ LOCA TED WITHIN SECTION 2; GOVERNMENT IX) I LOT 4 N LOT 4; TOWNSHIP 4 SOUTH RANGE 15 WEST, SEWARD MERIDIAN LOT 3 &' ~q. ~ ~QJ ~ .$'.:y ~. C,,' LOT 2 I- ..... ..... ~ l- I/) ~ ..... -J -J ~ :i U LOT 1 w ~~~~~~~. tC:;;ÞC>~ OF Â~~~\\ ~~·,··,·"···~~~~U 11$·' A ···.':r°o ~,~, /. .~~.:~. ... .... ",:7;. ~ ~ ¿4/? - /? -' ~ ~~~.. :.:.. 'M~;k' E'" '6~'~i~" :.:. ~ ~ Vl\oD...· . . ~~ vQiJI.... ". LS-7338 ..' (,:~ if? "C!I.... ". ..' I"_.::t..!f!i' IJ C!I '. ,'-J ~ ~t\.0' ,() .,'.....' r-b &::? ~t\. r \..0 C::? '\\~~~fessiono\ ~c:::7 '~~~~~~c::::::.C::::S JOB NAME: PHILLIPS PETROLEUM LOCATION: ANCHOR POINTE, ALASKA DRAWN BY: MD CHECKED BY: SCALE: 1 n = 300 DATE: 7 /2/01 JOB NUMBER SHEET 1 OF 1 '~,,/ ~ 1440 - ,--.... -+- 0) 2160 - 0) - '--" ..c 2880 - -+- D- O) 0 3600 - 0 () :;: 4320 - L 0) > 0) 5040 - ::J L l- I 5760 - V 6480 - CJ ::0 7200 - ~ C:~j 7920 - -..,.,.,~. ." -..".-'" - c:: ~: ~, 01 - .J:L 720 - For: B Lloyd Date plaited: 1B-Juf-20Dl Plot Reference is Hansen #1 V.11. Coordinales are in feet reference slot # 1. Vertical Depths ore reference Est. Î 63' RK8.~ ~éa BAKnl HUGHES INTEQ ESTIMATED RKB ELEVATION: 163' Beluga Conductor : 3.00 KOP 9.00 15.00 DLS: 3.00 deg per 100 ft 21.00 27.00 Tyanek 33.00 39.00 45.00 54.00 63.00 13 3/8 Casing v 720 1440 2160 2880 3600 4320 Phillips Alaska, Inc. Structure : Hansen # 1 Well: Hansen field : Exploration Location : Kenai Peninsula. Alaska ¡ ------~-- 297.02 AZIMUTH 14,263' (TO STARICHKOFF TGT) h.Plane of. Proposal... i it ~ ~ ~ ~ TRUE AVERAGE ANGLE 73.33 DEG Tgt Starichkoff Snd --.¿j 9 5/8 Casing Tgt B/Lower Tyonek B/Storichkoff Snd v Tgt Hemlock Tgt B/Hemlock TD - Casing /:"I:'I-~ "r'n L.i... r~ ". } - -- i ~ "' ~ --- 5040 6480 8640 9360 10080 10800 11520 12240 12960 13680 14400 15120 15840 16560 7200 7920 5760 Vertical Section (feet) - > Azimuth 297.02 with reference 0.00 N, 0.00 E from slot #1 C> ~. ~ t? ......' ~ ~ :to ~- Created by 'inch Lloyd Phillips Alaska, Inc. Well : Hansen Dote plotted; 18-Jul-2001 prot Reference is Hansen # 1 V.11. Coordinates ore in feet reference slot # 1. True Vertical Depths ore reference Est. 163' iTti=.¡¡¡ BAKlR HUGHES 14950 14300 13650 13000 12350 11700 11050 10400 9750 ~TO t>-..::. Casing pt B/Hemlock Tgt Hemlock B/Starichkoff Snd Tgt B/Lawer Tyonek 9 5/8 Casing ~ Tgt Starichkaff Snd 297.02 AZIMUTH 14,263' (TO STARICHKOFF TGT) ...Plane of Proposal." ~ ¿Th ~~ TRUE TO LOCATION: 886' FNL, 55' FEL SEC. 32, 13S, R 151'1, S.M. Field : Exploration ...----------------------- Location: Kenai Peninsula, Structure : Hansen # 1 9100 7800 <- West (feet) 5850 8450 TARGET LOCATION: 1 750' FNL, 1641' FWL SEC. 33, 13S, R15W, S,M. 7150 5200 6500 Lower Tyonek 13 3/8 Casing 4550 3250 3900 2600 1950 1300 650 ESTIMATED SURFACE LOCATION: 2331' FSL. 1493' FEL SEC. 2. T4S, R15W, S.M. o 7800 - 7150 '_ -w;ø/ - 6500 - 5850 - 5200 - 4550 ^ I - 3900 Z 0 :¡ - 3250 :::J ,--... -+. CD - 2600 ~ '--" - 1950 - - 1300 - 650 - 0 - 650 Phillips Alaska, Inc. ..oIIÎo... .......... ..... .í -.;-. .....-... "- (' PHilLIPS ~ by finch Dote plotted : Plol Reference is Honsen #1 V.11. Coordinates are in feet reference sIal # 1. Vertical Depths ore reference Est. 163' ;'~¡¡. BAlCER HUGHES structure : Hansen # 1 Well : Hansen Field: Exploration Location: Kenai Peninsula, ==== PROFijLE COMMENT DATA ==== Point MD Inc Dir TVD North East V. Sect Oeg/100 ......"..._f'!// ----- ----- Beluga 313.00 0.00 297.02 313.00 0.00 0.00 0.00 0.00 KOP 1000.00 0.00 297.02 1000.00 0.00 0.00 0.00 0.00 Tyonek 1929.23 27.88 297.02 1893.00 100.67 -197.45 221 .63 3.00 EOC 3444.29 73.33 297.02 2829.58 61 8.64 -1213.35 1361.96 3.00 13 3/8 Csg pt 7046.55 73.33 297.02 3863.00 2186.10 -4287.65 4812.80 0.00 Lower Tyonek 10323.15 73.33 297.02 4803.00 3611 .87 - 7084.03 7951.67 0.00 -12706.55 .....-/ Tgt Storichkoff Snd 16911.23 73.33 297.02 6693.00 6478.56 14262.82 0.00 9 5/8 Csg pt 16911.24 73.33 297.02 6693.00 6478.57 -12706.56 14262.84 0.00 C B/Starichkoff Snd 17556.08 73.33 297.02 6878.00 6759.16 -13256.89 14880.57 0.00 ::t:J Tgt B/Lower Tyonek 17556.09 73.33 297.02 6878.00 6759,17 -13256.90 14880.58 0.00 ---= ~~ ~¿=. Tgt Hemlock 17887.24 73.33 297.02 6973.00 6903.26 -13539,51 15197.81 0.00: ---.. ~-.. C::::.: ~ Tgt 8/Hemlock 18305.53 73.33 297.02 7093.00 7085.27 -13896.50 15598.52 0.00: . , ~~ TO - Casing...pt 18898.11 73.33 297.02 7263.00 7343.12 -14402.23 16166.19 0.00' .....___._ .. ...._....____.......____..___._.m__..._nn____._._________..___________________ - -------.-----------.-- - ---~----_._-------_.__._-_._. ..___.......mn...·m.___.._____..____._ ....m_..____m__...._...______·_·__..__ - __ .m. .____n___ _ . ) -'I j Phillips Alaska, Inc. Hansen #1 Hansen slot #1 Exploration Kenai Peninsula, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License Hansen #1 V.ll prop4583 Date printed Date created Last revised 18-Jul-2001 22-Mar-2001 18-Jul-2001 Field is centred on n60 48 21.994,w150 49 18.963 Structure is centred on 170306.12l,2142409.004,999.00000,N Slot location is n59 51 31.297,w151 48 4.685 Slot Grid coordinates are N 2144779.776, E 168876.865 Slot local coordinates are 2331.17 N 1492.86 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 0,11 (;i ¡¡VA L ) Phillips Alaska, Inc. PROPOSAL LISTING Page Hansen #l,Hansen Your ref Hansen #1 V.11 Exploration,Kenai peninsula, Alaska Last revised : 18-Jul-2001 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 297.02 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 297.02 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 297.02 300.00 0.00 N 0.00 E 0.00 0.00 313.00 0.00 297.02 313.00 0.00 N 0.00 E 0.00 0.00 Beluga 400.00 0.00 297.02 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 297.02 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 297.02 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 297.02 700.00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 297.02 800.00 0.00 N 0.00 E 0.00 0.00 900.00 0.00 297.02 900.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 297.02 1000.00 0.00 N 0.00 E 0.00 0.00 KOP 1100.00 3.00 297.02 1099.95 1.19 N 2.33 W 3.00 2.62 1200.00 6.00 297.02 1199.63 4.75 N 9.32 W 3.00 10.46 1300.00 9.00 297.02 1298.77 10.68 N 20.95 W 3.00 23.51 1400.00 12.00 297.02 1397.08 18.96 N 37.18 W 3.00 41.74 1500.00 15.00 297.02 1494.31 29.56 N 57.98 W 3.00 65.08 1600.00 18.00 297.02 1590.18 42.46 N 83.28 W 3.00 93.48 1700.00 21.00 297.02 1684.43 57.62 N 113.01 W 3.00 126.85 1800.00 24.00 297.02 1776.81 75.00 N 147.10 W 3.00 165.12 1900.00 27.00 297.02 1867.06 94.55 N 185.45 W 3.00 208.16 1929.23 27.88 297.02 1893.00 100.67 N 197.45 W 3.00 221.63 Tyonek 2000.00 30.00 297.02 1954.93 116.22 N 227.95 W 3.00 255.87 2100.00 33.00 297.02 2040.18 139.95 N 274.50 W 3.00 308.12 2200.00 36.00 297.02 2122.59 165.68 N 324.95 W 3.00 364.75 2300.00 39.00 297.02 2201.91 193.33 N 379.18 W 3.00 425.62 2400.00 42.00 297.02 2277.95 222.82 N 437.03 W 3.00 490.56 2500.00 45.00 297.02 2350.47 254.09 N 498.35 W 3.00 559.38 2600.00 48.00 297.02 2419.30 287.03 N 562.96 W 3.00 631.91 2700.00 51.00 297.02 2484.24 321.57 N 630.70 W 3.00 707.95 2800.00 54.00 297.02 2545.11 357.60 N 701.37 W 3.00 787.27 2900.00 57.00 297.02 2601.74 395.03 N 774.78 W 3.00 869.68 3000.00 60.00 297.02 2653.99 433.76 N 850.73 W 3.00 954.93 3100.00 63.00 297.02 2701.70 473.67 N 92 9.02 W 3.00 1042.80 3200.00 66.00 297.02 2744.74 514.66 N 1009.42 W 3.00 1133.05 3300.00 69.00 297.02 2783.01 556.62 N 1091.72 W 3.00 1225.43 3400.00 72.00 297.02 2816.38 599.43 N 1175.68 W 3.00 1319.68 3444.29 73.33 297.02 2829.58 618.64 N 1213.35 W 3.00 1361.96 EOC 3500.00 73.33 297.02 2845.56 642.88 N 1260.89 W 0.00 1415.33 4000.00 73.33 297.02 2989.00 860.45 N 1687.61 W 0.00 1894.31 4500.00 73.33 297.02 3132.44 1078.01 N 2114.33 W 0.00 2373.29 5000.00 73.33 297.02 3275.89 1295.58 N 2541. 05 W 0.00 2852.27 5500.00 73.33 297.02 3419.33 1513.15 N 2967.77 W 0.00 3331.26 6000.00 73.33 297.02 3562.77 1730.72 N 3394.49 W 0.00 3810.24 6500.00 73.33 297.02 3706.21 1948.28 N 3821.21 W 0.00 4289.22 7000.00 73.33 297.02 3849.65 2165.85 N 4247.93 W 0.00 4768.21 7046.53 73.33 297.02 3863.00 2186.10 N 4287.64 W 0.00 4812.78 7046.55 73.33 297.02 3863.00 2186.10 N 4287.65 W 0.00 4812.80 13 3/8 Csg pt 7500.00 73.33 297.02 3993.09 2383.42 N 4674.65 W 0.00 5247.19 8000.00 73.33 297.02 4136.53 2600.98 N 5101.37 W 0.00 5726.17 All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est. 163' RKB (163.00 Ft above mean sea level). Bottom hole distance is 16166.19 on azimuth 297.02 degrees from wellhead. Total Dogleg for wellpath is 73.33 degrees. Vertical section is from wellhead on azimuth 297.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ V Mi . ~ . . V n '- ) ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Hansen #l,Hansen Your ref Hansen #1 V.11 Exploration,Kenai Peninsula, Alaska Last revised : 18-Jul-2001 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 8500.00 73.33 297.02 4279.97 2818.55 N 5528.09 W 0.00 6205.16 9000.00 73.33 297.02 4423.41 3036.12 N 5954.80 W 0.00 6684.14 9500.00 73.33 297.02 4566.85 3253.69 N 6381.52 W 0.00 7163.12 10000.00 73.33 297.02 4710.29 3471.25 N 6808.24 W 0.00 7642.10 10323.15 73.33 297.02 4803.00 3611.87 N 7084.03 W 0.00 7951.67 Lower Tyonek 10500.00 73.33 297.02 4853.74 3688.82 N 7234.96 W 0.00 8121. 09 11000.00 73.33 297.02 4997.18 3906.39 N 7661.68 W 0.00 8600.07 11500.00 73.33 297.02 5140.62 4123.95 N 8088.40 W 0.00 9079.05 12000.00 73.33 297.02 5284.06 4341.52 N 8515.12 W 0.00 9558.04 12500.00 73.33 297.02 5427.50 4559.09 N 8941.84 W 0.00 10037.02 13000.00 73.33 297.02 5570.94 4776.66 N 9368.56 W 0.00 10516.00 13500.00 73.33 297.02 5714.38 4994.22 N 9795.28 W 0.00 10994.99 14000.00 73.33 297.02 5857.82 5211.79 N 10222.00 W 0.00 11473.97 14500.00 73.33 297.02 6001. 26 5429.36 N 10648.72 W 0.00 11952.95 15000.00 73.33 297.02 6144.70 5646.92 N 11075.43 W 0.00 12431.93 15500.00 73.33 297.02 6288.14 5864.49 N 11502.15 W 0.00 12910.92 16000.00 73.33 297.02 6431.59 6082.06 N 11928.87 W 0.00 13389.90 16500.00 73.33 297.02 6575.03 6299.63 N 12355.59 W 0.00 13868.88 16911.23 73.33 297.02 6693.00 6478.56 N 12706.55 W 0.00 14262.82 Hansen#l/Starichkoff Snd Rvsd 1-Jun-01 16911.24 73.33 297.02 6693.00 6478.57 N 12706.56 W 0.00 14262.84 9 5/8" Csg pt 17000.00 73.33 297.02 6718.47 6517.19 N 12782.31 W 0.00 14347.87 17500.00 73.33 297.02 6861.91 6734.76 N 13209.03 W 0.00 14826.85 17556.08 73.33 297.02 6878.00 6759.16 N 13256.89 W 0.00 14880.57 B/Starichkoff Snd 17556.09 73.33 297.02 6878.00 6759.17 N 13256.90 W 0.00 14880.58 Tgt B/Lower Tyonek 17887.24 73.33 297.02 6973.00 6903.26 N 13539.51 W 0.00 15197.81 Tgt Hemlock 18000.00 73.33 297.02 7005.35 6952.33 N 13635.75 W 0.00 15305.83 18305.53 73.33 297.02 7093.00 7085.27 N 13896.50 W 0.00 15598.52 Tgt B/Hemlock 18500.00 73.33 297.02 7148.79 7169.89 N 14062.47 W 0.00 15784.82 18898.11 73.33 297.02 7263.00 7343.12 N 14402.23 W 0.00 16166.19 TD - Casing pt All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from Est. 163' RKB (163.00 Ft above mean sea level). Bottom hole distance is 16166.19 on azimuth 297.02 degrees from wellhead. Total Dogleg for wellpath is 73.33 degrees. Vertical section is from wellhead on azimuth 297.02 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ O~ 'G 'Vt~ ) ) Phillips Alaska, Inc. Hansen #l,Hansen Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page Your ref Hansen #1 V.11 Last revised : 18-Jul-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 313.00 313.00 0.00 N 0.00 E Beluga 1000.00 1000.00 0.00 N 0.00 E KOP 1929.23 1893.00 100.67 N 197.45 W Tyonek 3444.29 2829.58 618.64 N 1213.35 W EOC 7046.53 3863.00 2186.10 N 4287.64 W 7046.55 3863.00 2186.10 N 4287.65 W 13 3/8 Csg pt 10323.15 4803.00 3611.87 N 7084.03 W Lower Tyonek 16911.23 6693.00 6478.56 N 12706.55 W Hansen#l/Starichkoff Snd Rvsd 1-Jun-01 16911.24 6693.00 6478.57 N 12706.56 W 9 5/8" Csg pt 17556.08 6878.00 6759.16 N 13256.89 W B/Starichkoff Snd 17556.09 6878.00 6759.17 N 13256.90 W Tgt BILower Tyonek 17887.24 6973.00 6903.26 N 13539.51 W Tgt Hemlock 18305.53 7093.00 7085.27 N 13896.50 W Tgt B/Hemlock 18898.11 7263.00 7343.12 N 14402.23 W TD - Casing pt Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OON O.OOE 500.00 O.OOE 7046.54 O.OOE 16911.23 O.OOE 18898.11 500.00 3863.00 6693.00 7263.00 O.OON 2186.10N 6478.56N 7343.12N O.OOE 4287.64W 12706.55W 14402.23W Conductor 13 3 I 8" Cas ing 9 5/8" Casing 7" Liner Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- Hansen#l TgtTD Rvsd 155308.000,2152215.000,0.0000 7093.00 Hansen#l/Starichkoff 156350.000,2151600.000,0.0000 6693.00 7065.13N 6478.56N 13764.78W 22-Mar-2001 12706.55W 27-Jul-2000 0= 'GINAL ) ) 3011 DIVERTER SCHEMATIC (on 3011 Structural, drilling 2411 well bore) Nabors 273 Hanson #1 ---6 L Open --------.... Closed ~ - - - - - - ~ To Accumulator I ,..., ... _ _ _ _ _ _ ..l I.... _. I : From i+ - - -. Accumulator 4 [: ~ Closed 3 -.__:1' D .-----~ ~ ~ 6~ Maintenance & Operation Open 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately I 2 l 2. Close annular preventer/open the valve in the event that an influx of wellbore fluids or gas is detected. 1 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES ~ -/ 1. 30" Structural Casing 2. 30" 500 psi Slip-on Weld Flange 3. 30" Diverter Spool with API 30" 500 psi Flanges 4. 30" Hydril MSP 500 psi Annular Preventer 5. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 6. 16" Diverter Line U'" ':i ~.~I '1 Rev., 07 /.16~0..1 r1kUlr~fiL --.b J ) ) 3011 DIVERTER SCHEMATIC (on 2011 conductor, drilling 17-1/211 wellbore) Nabors Rig 273 Hansen #1 7 L Open ---------.¡ I r - - - - - - ~ To Accumulator I Closed ' , , +______-1 L_+ [ ¡ I :.. _ _ _ . From Accumulator Closed -. _ _.t D------.... Open 6 SV-~ 8 9 LN \, Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 5 2. Close annular preventer/open the valve in the event that an influx of well bore fluids or gas is detected. 4 3 2 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES ~ ~ 1. 20" Conductor Conductor 2. 30" Structural Casing 3. 30" 500 psi SOW Flange 4. 30" 500 psi X 20-3/4" 3000 psi, Casing Head W/4" x 3000 psi flanged outlets 5. 20-3/4" 3000 psi x 30" 500 psi Diverter Spool 6. 30" Hydril MSP 500 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line wbl, Rev. 07/17/01 Vj~¡~~'Î~rlL.. ) PHilliPS Alaska, Inc. J 13-5/811,5,000 PSI. BOP STACK NABORS 273 Hansen #1 ---.1 c:L.- ~ ~2¿ ~ 2.0" c:~:~~ace casing . ~ 3-3/. dia\e casIng 9-5/6" In\erme ~ 4-1/16" CIW ~ I 5,000 psi WP Manual Valve ~ C~~~~U T~ 4-1/16" CIW ~ HCR I 5,000 psi WP 7 ~ 6 4-1/16" CIW 5,000 psi WP Manual Valve 5 4 þ 4-1/16" CIW HCR 5,000 psi WP ¿ 3 1. 30" 3M x 20-3/4" 3M starting head w/4" flanged outlets. 2. Casinq Spool: 20-3/4" 3M x 13-5/8" 5M w/2 - 4" x 5M psi flangerd outlets: 3. Casinq Spool: 13-5/8" 5M x 13-5/8" 5M w/2 - 4" x 5M psi flanged outlets. 4. Sinqle Pipe Ram: 13-5/8" 5M psi WP, Hydril MPL with pipe rams. 5. Drillinq Spool: 13-5/8" 5M psi WP with (2) 4-1/16", 5M psi WP kill line outlet & (2) 4-1/16", 5M psi WP choke line outlet 6. Double Pipe Rams: 13-5/8" 5M psi WP, Hydril MPL with pipe rams on top and blind rams on bottom. 7. Annular Preventer: 13-5/8" Hydril GK 5M psi WP top flange x 5M psi WP bottom flange. Accumulator Capacity Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time. Then, with the charging pump(s) off, close all units simultaneously and record the elapsed time and remaining pressure after all units are closed. Record results on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test Fill BOP stack and manifold with water. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. Close annular preventer, chokes, and bypass valves on the manifold. All others open. Test all components to 250 psi and hold for 5 minutes. Increase pressure to 5000 psi and hold for 10 minutes. Bleed back to zero psi. Open annular preventer and manual kill and choke line valves. Close top pipe rams and HCR valves on kill and choke lines Test to 250 psi for 5 minutes and 5000 psi for 10 minutes. Continue testing all valves, lines, and chokes with a 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Do not pressure test any choke that is not a full closing positive seal choke. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi for 5 minutes and 5000 psi for 10 minutes. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi low for 5 minutes and 5000 psi high for 10 minutes. Bleed to zero psi. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. Test standpipe valves to 5000 psi for 10 minutes. Test kelly cocks and inside BOP to 5000 psi for 10 minutes with BOP test pump. Record test information on blowout preventer test form and on pressure chart. Sign and send to drilling engineer. Perform BOPE test a) when initially installed, b) whenever any seal subject to test pressure is broken, c) following related repairs, and d) at 7 day intervals. Functionally operate BOPE daily. Pit drills are to be conductled weekly for each drilling crew. O,:'GfNt~ ) All Depths are RKB Nabors Rig 273 Hansen #1 FMC Gen V l. 13-3/8 x 9-518 r 13-318" -~ .. L i Mandrel Hanger "'~~,,--, ----·WW"I i .... 13-3/8" Port Collar ....[. . @ 1000' MD 7,047' MD 1 3,863' TVD . 17-1/2" Hole 13-3/8" 72 ppf L-80 SL "BOSS" Surface 12-1/4" Hole 9-518" 53.5# (special drift) and 47# L-80 SL "Boss 16,911' MD 1 6,693' TVD .. .. 2r ..... 8-1/2" Hole 1'1 26#/ft L -80 Buttress Baker 7" Landing Collar, Float Collar and Float Shoe (2 jt. spacing between each) .. . II z.... ...... .. . k ) Drill and Set Casing ~¿, , I ~I ....... ... .... ... .. ... . 20" Conductor @ 700' . . Mud Weight in Surface hole: 9.0 - 9.4 ppg, LSND Spud Mud L Davis Lynch 13-3/8" Tag-In FC and Float Shoe Mud Weight in Intermediate hole 10.0 - 10.6 ppg, Invert Emulsion Oil-based Fluid Baker 7" x 9-518" ZXP L TP and tieback sleeve and HMC Liner Hanger w/PBR @ 16850' MD Davis Lynch 9-5/8" Float Shoe and Float Mud Weight in Production hole 9.0 - 9.2 ppg, Invert Emulsion Oil-based Fluid II f~ ï ~ I ¡J IiJ ¡>-Ú '- '\ , Hansen #1 WELLBORE SCHEMATIC and CEMENT DESIGN 20" Conductor Casing at 700' MD 1 RKB 13-3/8" Surface Casing at 7,047' MD Top of Cement at 15,900' MD 9-5/8" Intermediate Casing at 16,911' MD 7" Production Liner @ 18,898' MD to 16,761' MD f:~ W~\ 1'~ 112-114 Bol, ~f ~'I :~+ l 1{ t ;r)i: ). t" ~ ¡::> ~¿; .;~~ "'¡ i+ ~ 8-1/2 Hole ~t. L. ) Conductor Casing Size / Hole Size 20" in 24" hole Depth: 700' MD RKB Top 01 Cement Surface Excess Calculated: 250% Volume Calculations: Lead Slurry (400 II) (0.9599 cl/ll) (2.50) = 960 ct (960 cl) 1(1.97 cl/sx) 490 sx Tail Slurry (300 ct) (0.9599 ct/ll) (1.00) = 288 cl (288 cl) 1(1.16 ells x) 250 sx Slurry Volume: 1,248 cf or 740 sx Slurry Weight 12.8 ppg and 15.8 ppg rounded Slurry Yield 1.97 cu. Ftlsx and 1.16 cu. Ft./sx Suñace Casing excess 13-3/8" in 17-1/2" hole Volume around 13-3/8" (1,000 II) (0.9932 clllf) (1.00) = 1,986 cl (5,847 II) (0.6946 ct/ll) (2.00) = 8,123 cl (500 II) (0.6946 clllt) (2.00) = 695 cl Lead (9,116 ct) 1(2.10 cl/sx) ~ Tail (500 II) (0.6946 cl/ll) (2.00) = ~ shoe joint vol 33 cf + (695 ct) 1(1.15 ells x) ~ System: Lead (Class G + 2% D79 (ext.)+ 0.5% S1(CaCI2) + 0.25 pps D29 @ 12.5 ppg) Tail (Class G + 1 % S1 (CaCI2) + 0.25 pps D29 @ 15.8 ppg) Lead Slurry Volume: 10,109 cf or Slurry Weight 12.5 ppg Slurry Yield 2.10 cflsx Thickening Time 4.0+ hours Tail Slurry Volume: 695 cf Slurry Weight 15.8 ppg Slurry Yield 1.15 cflsx Thickening Time 3.5 - 4.5 hours 1302 F BHT (Circ): excess Volume around 9-5/8" (1,011 II) (0.3132 cl/lf) (1.50) = 475 cl Lead (237 cl) 1(2.09 cl/sx) (1.50) = 140 sx Tail (237 ct) 1(1.15 cl/sx) (1.50) = 240 sx shoe joint vol 33 cf + 1(2.09 cl/sx) .1ß..ßlç System: Lead (Class G cement + 2% D79 + 0.25% D800 + 0.25 pps D29) Tail (Class G + 0.25% D65 + 0.2% D167 + 0.06% XE920) Lead Slurry Volume: 240 cf or Slurry Weight 12.5 ppg Slurry Yield 2.09 cflsx Thickening Time 3.5 - 4.5 hours Tail Slurry Volume: 268 cf Slurry Weight 15.8 ppg Slurry Yield 1.15 cl/sx Thickening Time 3.5 - 4.5 hours 17-112 Hole Intermediate Casing Size I Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): 16,911' 15,900' 50% 1602 F Production Casing Size / Hole Size Depth: Top 01 Cement Excess Calculated: BHT (Static): ~ Class G or ~ Class G 9-5/8" in 12-1/4" hole liQ..§,¡¡ Class G or ~ 7" in 8-1/2" hole 18,898' 16,561' 50% 1602 F 1302 F BHT (Circ): excess Volume around 7 Vol. Between liner & Int. shoe joint val 17 cf + (378 ct) Volume of 200' above liner System: (Class G + 0.25% D65 + 0.3% D167 + 0.06% XE920) (1,987 It) (0.1268 cl/ll) /(1.15 cl/sx) Slurry Volume: 499 cf Slurry Weight 15.8 ppg Slurry Yield 1.15 ct/sx Thickening Time 3.5 - 4.5 hours (1.50) = 378 cl ~ 344 sx ªº-.g or ~ Class G 7/18/01 U I"i' U I j~j-IL. ) ) PHILLIPS PETROLEUM COMPANY To: Bob Swenson ATO-1368 Paul Anderson ATO-1300 William Lloyd ATO-1566 From: Kathy Heinlein ATO-1346 Subject: Pre-Drill Seismic Pore Pressure Prediction for Hansen #1 Date: June 24, 2001 Summary Seismic velocity data was used to predict pore pressures likely to be encountered in the proposed Hansen #1 well location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from the Starichkof St #1 offset well. The local compaction trend and the translation trend model were applied to velocities from 20 seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well locations. Seismic ProcessinQ The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used for pressure prediction were generated using an automated high-resolution velocity analysis program. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 COPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in COP fold. After velocities were calculated and smoothed, a scale factor (constant value) was applied to calibrate the seismic velocities to velocities measured at the Starichkof St #1 well. 01 ! ~ 'NA~ t J Pressure Prediction Procedure Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. The Starichkof St #1 offset well (Figure #1) was used to· establish both a local normal compaction trend line and local velocity vs. pressure translation trend model. Procedure 1.) A Normal Compaction Trend Line (NCTL) was determined for three 2-0 seismic lines (180-70, SK95-1, WLC-1002). The seismic-derived NCTLs matched the NCTL slope calculated at Starichkof #1 (-3.94e-5). The intercept varied slightly from the intercept found at the well (150 seismic vs 141 well) prior to scaling; after scaling the seismic intercept matched the well intercept (141). 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (~T) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, ~~ T. 3.) A translation trend model was established by comparing transit time differences (~~ T) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C3**~~T**3 + C2*~~T**2 + C1*~~T + CO Where C3 = 5.0e-6, C2 = -0.000468, C1 = .012345, CO = .470487 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile. Seismic Pore Pressure Prediction Pressure gradients were predicted for the Hansen #1 proposed well location using 20 seismic data in close proximity to the proposed borepath (Figure #2). Pressure gradient prediction displays are provided for seismic line 180-70, both in time and in depth. Predicted Pore Pressure Gradient Oisplays in Depth: Fiqure # Seismic Line 3 180-70 Predicted Pore Pressure Gradient Oisplays in Time with Migrated Time Overlay: 4 180-70 0. ~, 'G" r ) ¡~ ) } Warmer colors indicate higher predicted mud weights (pore pressure gradients). No apparent shallow hazards are observed in the seismic pressure analysis. It is important to note that the seismic velocities above 1500 feet are considered unreliable for pressure prediction in this area. Pore Pressure Gradient Prediction at Proposed Hansen #1 Well Location Figure # Seismic Line Well Location 5 180-70 Hansen #1 (td) Conclusions 1.) There are no apparent shallow hazards at the proposed Hansen #1 well location observed on regional 20 seismic data (180-70, SK95-1, WLC-1 002). 2.) The normal compaction trend observed in the Starichkof St #1 well matches compaction trends observed in the 20 seismic data. 3.) The pressure values predicted by the seismic analysis match the pressures measured by OST tests run at the Starichkof St #1 well. Kathy Heinlein ORIl;{UVAL I'PHI~PS' ~ ~ (" ""'" &. ~ ! Ii< or. r. to. t PHilliPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 6/24/01 K. Heinlein Project: Hansen #1 Well: 8tarichkof 8t 1 Starichkof St #1 DEPTH (DeJum $etfo MSL) MSL . . ÙCbiL ' IU~ , , ~-¡ . - j, ' 1000 -- - ---- ---- _--0__--'- -~ ------upper Tyonek - -- ----- _0_- _________ Method: Trend Curve NCTL: 141-3.94e-5 Model: Cook Inlet FEEl MSL 1000 I J. ~ -0 ~ ~_u______u_____________________ 2000 -~-~-~~~m_:""::"- ~~~-- ....:-~==-=-- ..-:.---~=-----:..---=-~~-=---:- ~=- :--:--~ 3000 -~ .. ~~__ __-~~-=_-~~--=~-~~~~"~.*~---- 5000 . 0 ... 0 --~~ ----------- -- ---~-6000 . ~-- .~X--- ~X ßJlpai- .-- - - 0-- ------ __un ------- - - ; _iil~ -; ~ t-· ~ .. ~..IIII· . . · · · · · · · . · . · . . . . -:. . . . . . . . . . . . . . . . . . . ....... . . . . . I: . ---. -:. --,: ~~ ~ ----x-mtptr ----,& -- _ Hèinloclc ~- 7000 . 0 ~ _ _ _~ "eat foreland --~" .. -~--=. ....- 2000 3000 - ~---------=---=~ -- -- --- ------ -- -- --- _. ___ _ --¢- m---'--___ ------------ --- ------- 4000 5000 6000 7000 -- -. - : 8000 9000 o 10000 r' -- ---- -- -·0--: ---0----;--- -----r .--- - - ,--___ I ------- ----- 0- -.----------.------ --- ------ 11000 -~---_.- - ,~~~----_._~_.__...- - - _.~" _0_- - - -------- -- 12112 - 40 60 80 100 120 '40 180 8 HCTL Intercept II GL = 141J1l Logarithmic Slope = -3 JG13e-15 ~ Cuing Depth * Kick I flow + Repeat formation Telt )( Drill stem Telt Ii Production Prellure eI Leak-off Telt 181 Loll Circulation Zonea - Formation Top ... stuck Pipe Location .... Sidetrack Location x freefDrm 13 14 15 12 PPG -e--- FINAL _ PPTC (Sonic NCTL: 1_ ZONE _ 44PSI, Top Trend Model: TEST _PPG _ XPLOT) - Mud Weight: DRILLERS _LOG 9 10 11 4000 8000 -- 9000 10000 ~' - -- 11000 12112 16 Figure 1 6HI~I,$\· ~ \~¡ PHilliPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 6/24/01 K. Heinlein Project: Hansen #1 Basemap -8 o ..-.6 _ co .... - c.; --- _I I II I I , II I I II III 521000 W 15206 00 W - § -0 ,.,. .... - c; -- 8 o -õ U') -- c.; - 8 Q "-~ -- c.; - J 8 ·0 ;--g -- .... roi a ~ ~~; ......... f;~ N § ~ -6 ~~ 00 I I I 110.000 I I I , I -.,.,.~- ~ ~~ "='- ." ~ Figure 2 C> -- -=:' ~ !:- "-- .... ~ :2- t'" PPO_I_24_Z t;HI~PS'\ ~ ~ PHilliPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 6/24/01 K. Heinlein Project: Hansen #1 Cross Section: 180-7D Method: Trend Curve NCTL: 141-3.94e-5 Model: Cook Inlet Seismic Line 180-70 (Depth) HANSEN 1 TO 1- STARlCHKOF ST 1 1- - 2000.0 D 3000.0 E P T H fit 4000.0 5000.0 6000.0 7000.0 - -~?-'-~:~ ~E ~ _. ~~ ~ :~E:-~ :-~~ ~ ---." ~-- -_. -->- _._....::._~- ~ 8000.0 CD P Interval = 20.5 ft '" 8.00 8.50 -- 9.00 9.50 10.00 10.50 11.00 11.50 12.00 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 ~ 16.50 I::: 18.00 18.50 19.00 ~- Figure 3 C) ::J::J ---- ~ ......... ~ ,........ ~HI~IPS '\ ~ ~ 141 ICAVEL PPC , lel;.lc: Acë_MICi T I tit 700.0 E ~..þ 800.0 900.0 1000.0 1100.0 1200.0 1300,0 1400,0 1500,0 1600.0 PHilliPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 6/24/01 K. Heinlein Project: Hansen #1 Cross Section: 180-7D Method: Trend Curve NCTL: 141-3.94e-5 Model: Cook Inlet Seismic Line 180-7D (Time) HANSEN 1 TO 1- ST ARICHKOF ST 1 1- - CD P Interval = 20.5 ft ... 8.00 ~- 8.50 9.00 9.50 10.00 10.50 11.00 11.50 12.00 12.50 13.00 13.50 14.00 14.50 15.00 15.50 16.00 16.50 17.00 17.50 18.00 18.50 19.00 --- Figure 4 /PHI~IPS' ~ ~ C ::0 ---- ~ ---- ~ .......... PHilliPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 5/22/01 K. Heinlein Project: Hansen #1 Well: Hansen #1 NCTL: 141-3.94e-5 Hansen #1 TO Location: Velocity from Seismic Line 180-70 1000 FEEl :__-_ _ _-'~ -'-L ~~r ___ ~_- ~~_--~-_~ _:_~~~~=:_::~-;-----~-~~=--~~-~_~~=-~=--=--~~ _-_:- _ _~:-~~-~ MSL .:.-. ~- . ,"j-~~~_~~ ~ ~:S~=~~~~= ~;~-~~;==~-~~~~_-=~_~=--~=~=. .1000 ... _~_~j =_-~~~ --_~~~-~:-=~;==-=~~-~:~~~~-~=~~~~=~~;=-=~-~-=-- 2000 ---~j-- ~- .~~:~~~~~-~ ~~~-=-~~:~-~:-~-----=~=- ---------=~~----: :;~--:-:----~----~=---=::---~~--~:_~::~:~-~~~~=~-=- DEPlH (DabJrn $etto MSL) MSl 2000 - - .. ____________ ______ _n_ __ _ __ _ - n_ _ _ ._______ __._ -- .. ----- --- -- - -----0----- -- --------- - - - -- ----- -------- ----- -- - - -- -- --- - ---.---- ------- - -- ------- 3000 3000 . ... - ""- --- . - -- - ------ ------ .. - - - ------ ----- -.-- -- -- - - ----- ------ - - ------- -------- -- ------- - - ------ - ----------- - - - ----------- .. -- - - -- --- --- ------ -- - -- - - - - ------- - ___ ___~_=___:...._ u_ __un_--=-: ::-_~~__ __ __ ----.---------- -- --- - ------------- ---- --------- ---. -- - - n_. _ ______ __ - n n___ __ .___ _ _ - ----- -- -- - ---------- -- - -- - - --- -------------- - ---- - -- -- --- -- --- --- --- --- ----- - - - -- -- - --. -- ----- -- ----- - - -- -- -- ---------------- __ __ ____n___n_nnn___ ___n________ _ - 4000 4000 ~ - - __ __ - - __.n_____.__ _ _ __ - ------- 0 - - ---.--------------- - - - --------- - - _n_ _ _ _ _ - ----.-- ----- - - -- - --- --- ---.--- --- ---- - - - n_ ____ ___ - -- --- - - ---- - --- - - - - - - _n______..___ n___ nn _____u____._ _ - -- - - --------- - ----- -- - _n_ _"_ __ - - __ __ ____________ n______ . - - -- -- - - -------------- - _n__ nn _________ _ __ - _____n___. ______ u u_ - - -- ---------- ---- ----0 - _n __________ __ _ --- - ------------- --- -- - - - --- -- :-~-=--- 5000 5000 . -'..-"-- --......--- -- ------ --- -- ------ - - --- - ---------- - - -------- - ------------ ------------ - --- ----- - --------- --- --------.--------- --- - - ------ _ - _ _ _...:~:_=_----~ - _0_ _ _ ____=-_--::::-:"-=--::.:::---:----- -- - - ---------------------- --------- - - - ---- - - --- ----- -- - - -------- ---- - - --------- - - - ------ - - --- --------------- -- -------------- - - ---------------- - - --------------- - --------- --- - ------------- - ---------------- --- &000 - - - - -- -.--- __ __ - __ un __. ____ __ _ 6000 - \-- -- - -- - -.- - - - ---- - -:~...:~~---=-=~=- : - -- -- - ---------------- -- --- - - ------------ -- - - __ n__n_..__________ _ _ _ ___un._____ ____ ___ _ _ ____ __ n_____ _ _ __ __n___._ _________n__________ - - - --.- - - _ l . ------- -- ------------ - - - ------.- --- --- - - -- ----- -- _ _ __----.:.9____ _ -- -------- - -- ---- _nu _ _ _____ ______ __ ____ ---- ---- -- 1070 - - h_ -~ - 40 60 60 100 120 140 160 NCTL Intercept at GL = 141 Logarithmic Slope = -3 J4e-15 --e--- PPG -' J4 _ Z -- - - -------- --- - ---- -- --- 1010 15 16 11 12 13 PPG 14 10 '-' -" Figure 5 1 ,000' - 2,000' ~ 3,000' -- 4,000' - 5,000' 6,000' 7,000' - 8,000' - 9,000' - 10,000' - 11,000' -- 12,000' -- 13,000' - 14,000' - 15,000' - 16,000' - 17,000' - 18,000' - ) ) Phillips Alaska Inc, Exploration Drilling Hansen #1 0' Drill conductor 10le Set 20" conductor casing brill ;7-Ü2iisurface hole Set 13-3/8" 5 JrfaCêC1rslng Drill 12-"/4" intermediate hole Dril 8-1/2" production _.__________._......______1 19,000' -------..--.--------..--..-.-- . 10 20 30 40 50 60 70 Days Planned -&- Actual I ~¡ I I ! I I I i I I ! I ¡ ! ~ ¡ ¡ ! ! 1: ¡ j j Run 7" liner, conplete, test, and P&A 80 90 100 110 J: GJ9^~A_ ) ) ODen Hole Setting Centralizer Placement Casino Size §iu Depth Style Dept~ Number 20" 24" 700' Non-Weld STA4 Bottom Joint 2 1 every other joint " " II II to 300' 4 II " II " 1 inside structural 1 13-3/8" 17-1/2" 7000' Tandem Rise TR3 Bottom Joint 2 " " " Spiraglider 1/joint to 6600' 9 One on either side of TAM collar @ " " " Non-Weld STA4 1000' 2 9-5/8" 12-1/4" 16911' Tandem Rise TR2 Bottom Joint 2 Every joint to " II " Spiraglider 16650 5 Every other joint " " " Spiraglider to 15900 8 1/joint to above 7" 8-1/2" 18898 Spiraglider and below zone 25 (est) (liner to 16700') ) ) STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _X Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Other Variance Annular Disposal X I 6. Datum elevation (OF or KB feet) RKB 30 feet RKB elev. Approx. 120· 7. Unit or Property name 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1878' FSL, 1566' FEL, Sec.2, T4S, R15W,SM At top of productive interval 1758' FNL, 1643' FWL, Sec. 33, T3S, R15W, SM At effective depth Cosmopolitan Project - Hansen #1 8. Well number 1 9. Permit number / approval number (proposed) At total depth 1172' FNL, 585' FWL, Sec. 33, T38, R15W, 8M (proposed) 12. Present well condition summary 10. API number N/A 11. Field / Pool Wildcat "':.~\>(:,c..~~ ~'-( ~a~-OO(o This Sundry Application requests authorization to dispose of drilling wastes by annular injection in the referenced well. Details of application are attached. RECEIVED JUL 232001 Additional details will be provided after well installation and leak-off test are completed. Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal _ D&tailed operations program _ BOP sketch Schematio . Reter to aUacÞed morning drilling report for LOT test. surface cement details-anctcasrng detarl sheets- --=..:-X .. I· 14. Estimated date for commencing operatIon 15. Status ot well clasSification as' November 1,2001 16. If proposal was verbally approved Oil_X Gas Suspended_ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed:~ 0~ lï~e: Drilling Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- Questions? Call Paul Mazzollnl 263-4603 ð~/08/ Date () I Prepared by Jean Bodeau Approval no. l ç. '"-~O -~ \ () Approved by order of the Commission Commissioner Date DUPllCATE Form 10-403 Rev 06/15/88· SUBMIT IN TRIPLICATE ) ) ~~~ PHIWPS PHilliPS Alaska, Inc. lÐ A Subsidiary of PHILLIPS PETROLEUM COMPANY Paul Mazzollni Exploration DrIlling Team Leader Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4603 Fax: (907) 265-6224 Email: pmazzol@ppco.com June 11,2001 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, AK 99501-3539 Re: Annular Disposal of Drilling Waste Cosmopolitan Project - Hansen #1 Dear Commissioner: Phillips Alaska, Inc. plans to drill up to two wells with two sidetracks as part of the Cosmopolitan Project exploration program in 2001-2002. The drill site is located on land owned by Mr. John Hansen near Anchor Point, Alaska. We request AOGCC authorization to dispose of drilling waste by annular injection in the Hansen #1 well. In support of this request, we submit the following information: . Application for Sundry Approvals Form 10-403 · Supplemental information, included below · Memo from Wayne Campaign (5/10/01) regarding Shallow Salinities for the Cosmo Project Area SUPPLEMENTAL INFORMATION The information provided in this section is presented to comply with State of Alaska regulations, as outlined below. 20 AAC 25.080 ANNULAR DISPOSAL OF DRILLING WASTE. (a) A person may not dispose of drilling waste through the annular space of a well unless authorized by the commission under this section. The operator of a well permitted under AS 31.05.090 may request authorization for the disposal of drilling waste through the well's annular space by filing with the commission an Application for Sundry Approvals (Form 10-403) supplemented with additional information as required under this section. b) A request for authorization under this section must include the following information or refer to that information if that information is already on file with the commission: ( 1) The annulus to be used for disposal; The annulus for which the request for annular disposal is being made is the 13 3/8" by 9 5/8" annulus of the referenced wellbore. o ~, 'G 'NA_ ) ) Phillips Alaska, lnc. Cosmopolitan Project - Hansen #1 Application for Annular Disposal (2) the depth to the base offreshwater aquifers and permafrost, ifpresent. TDS (NaCI equivalent) calculations on electric logs in Anchor Point #1 well (7.5 miles south) show a gradual increase with depth, with an average TDS greater than 4,000 ppm below about ~\) 3,500 feet. The Hansen #1 injection zone is planned to be at 3,700 ft. interval which averages 4,000 ppm TDS. All permeable sands below 6960 ft. are above 10,000 ppm. Please see the attached memo from Wayne Campaign regarding Shallow Salinities for the Cosmo Project Area for more information. 'Fresh' water « 1 0,000 ppm) will be encountered from the surface to near the top of the oil bearing zone because the Tertiary sediments were all deposited in a non-marine setting. Saline water is only introduced into the porous parts of the section when in communication with the marine Mesozoic age rock and migrated from below the lower Tertiary unconformity. At times, this migration also carries oil which is sourced from Jurassic aged rocks. The insitu water was likely entrained during early deposition and burial and had initial TDS of <500 ppm, but was altered by reaction with surrounding strata during diagenesis. Meteoric recharge into any of these 'freshwater' aquifers will be controlled by the presence of viable migration pathways which must pass though the laterally continuous, and vertically ubiquitous mudstone and claystone layers. These layers are normally impermeable unless cut by a major fault that is not later inundated by diagenic cements or sealed by 'shale-smear'. The vertical sealing capacity of these intervals is evidenced by the occurrence of shallow gas reservoired in some of the sand intervals where in a trapping geometry is present. (3) a stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or, except to the extent allowed under (e)( 1) of this section, contaminate freshwater; The interval targeted for disposal is a permeable sand stringer in the Tyonek formation, at probable depth of 3700' TVD in the nearby Anchor Point No. 1 well. This permeable sand stringer will be below the proposed casing shoe. The stratigraphic interval targeted for injection is within the upper Tyonek Formation. Lithologically, the upper Tyonek is composed of interbedded coal and fluvial clastic units including overbank mudstone, clay, siltstone and sandstone. The sand lenses are laterally discontinuous and likely deposited within paleochannels and as crevasse splays. Lithologic control and lateral continuity is obtained from Anchor Point #1 and Starichkof State #1 wells with Anchor Point providing the most reliable information as to sample description and log character. Relative permeability of the clastic units can be determined from a micro-resistivity and SP log suite and show the high permeability sand lenses encased in hundreds of feet of impermeable, finer grained units (see well log of 3700' interval). A freshwater exemption is requested for this annular injection well. As noted above, the TDS of the target formation was determined to be approximately 4000 ppm, which is within the range for which the exemption is allowed, according to federal and state regulation. The proposed injection formation is not now and will not in the foreseeable future be used as a source of drinking water. The depth of the formation is such that producing water from this zone for drinking water would be economically and technically not feasible. There are numerous other sources of drinking water in the area that could provide sufficient water for significant development at a more reasonable cost than this formation. At present, there is only one water well in Alaska greater than 1000 feet deep. Page 2 of 5 O~ 'G,AA~ ) Phillips Alaska, Inc. Cosmopolitan Project - Hansen #1 ) Application for Annular Disposal (4) a list of all publicly recorded wells within one-quarter mile, and all publicly recorded water wells within one mile, of the well that will receive drilling waste; There are no oil or gas wells within % mile of the project site. Water wells are listed below. PUBLICLY RECORDED WATER WELLS WITHIN ONE MILE OF SITE (from Alaska Division of Water) Alaska Owner at Depth USGS # - Legal Description Date Drilled Key Time of (ft) Township Installation Range 015540 ESKELSON, 0055 SC003- 015- JEPPESEN L08 07/03/88 MATHEW 36DC 023455 WALLACE, 0069 SC004- 015- WALLACE TR 1 / / ROSELLA 01ABBB 021852 ROMPH, 0056 SC004- 015- FUHR TR- 4 01/01/76 RONALD 01BC 020132 MUMEY, 0000 SC004- 015- STARISKI HTS L2 / / DANIEL L. 01BCAB 019968 COOPER, 0124 SC004- 015- STARISKI HTS L1 08/ 16/84 ERIC 01BCAB 1- 3 018108 USGS 0059 SC004- 015- KENAI WELL #03 10/05/79 01CCDD1- 2 022394 WALLI, 0086 SC004- 015- ANCHOR PT 06/01/78 ROBERT 02AABB 017835 MILLER, 0030 SC004- 015- CH MILLER L2 07/30/89 GEORGE 02DC 017836 JORDAN, 0030 SC004- 015- CH MILLER L1 08/ 15/ 89 TERRY 02DC 020133 INMAN, 0063 SC004- 015- STARISKI PRK L01 B2 01/01/ 74 DAVID 11ACAA 019969 CHAMBERS, 0155 SC004- 015- STARISKI PRK L5 B1 03/07/83 KEVIN 11ACAB1- 5 OTHER WATER WELLS WITHIN 1 MILE OF SITE NA HANSEN, 30 SC004-015- DUGWAY LOT 4 UNKNOWN (Informat JOHN & 1CBAD ion from VIOLA well owner) (5) the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry; The estimated volumes and description of waste to be disposed of is 20,000 barrels of water base mud and cuttings and 15,000 barrels of oil based mud and cuttings. The maximum volume to be disposed would be 35,000 bbls. The slurrification will result in a fluid density of approximately 10 - 12 pounds per gallon. Page 3 of 5 o.:G '^ A__ ) Phillips Alaska, Inc. ) Cosmopolitan Project - Hansen #1 Application for Annular Disposal (6) a description of any waste sought to be determined as drilling waste under (h)(3) of this section; No additional fluids or waste other than what is covered under section "h" (1) and (2) should be required. (7) an estimate of the maximum anticipated pressure at the outer casing shoe during disposal operations and calculations showing how this value was determined; The maximum anticipated pressure at the casing shoe is determined as follows: TVD of Shoe: 3700' (approximate) Mud weight in annulus 10 - 12 ppg Hydrostatic pressure Depth x Mud Weight x 0.052 = BHP 3700 x 10.0 x 0.052 = 1924 psi 3700 x 12.0 x 0.052 = 2309 Anticipated maximum fracture pressure 1 psilft = 3700 psi Maximum anticipated surface pressure = Max frac pressure - BHP (hydrostatic) = 3700 - 1924 = 1776 psi. = 3700 - 2309 = 1391 psi Based on these calculations, the maximum anticipated surface pressure is 1,776 psi. (8) details that show that the shoe of the outer casing is set below the base of permafrost, if present, and any freshwater aquifer, other than freshwater excepted under (e)( 1) of this section, and is adequately cemented to provide zone isolation; the information relied upon and submitted must include: (A) cementing records; and (B) a cement quality log or formation integrity test records; The 13 3/8" surface casing will be cemented to surface. A cement evaluation tool will be used for cement evaluation. A Formation Leak-Off Test will be conducted by drilling 10-20' below the casing shoe and testing. (9) details that show that the inner and outer casing strings have sufficient strength in collapse and burst to withstand the anticipated pressure of disposal operations; The table shows the proposed strings of casing for the Surface and Intermediate Hole Sections. Note that the properties of the proposed strings have a Factor of Safety of 1.45 for the burst requirements of the 13 3/8" and 1.79 for the collapse requirements of the 9 5/8" casings. Casing 13 3/8" 9 5/8" Weight IGrade 72 lblft N-80 53.5 lblft N-80 Collapse 2,670 psi 6,620 psi Burst 5,380 psi 7,930 psi Factor of Safety Burst 1.45 Collapse 1.79 (10) the downhole pressure obtained during aformation integrity test conducted below the outer casing shoe; A leak-off test will be performed upon drilling no more than 20' of additional hole below the 13-3/8 casing shoe setting depth. The results will be sent to AOGCC once testing has been completed. Page 4 of 5 c: 'GINAL ) Phillips Alaska, Inc. ) Cosmopolitan Project - Hansen #1 Application for Annular Disposal (11) identification of the hydrocarbon zones, if any, above the depth to which the inner casing is cemented; The intermediate hole is not anticipated to encounter any hydrocarbon bearing sands. There will be coal stringers. Any hydrocarbon bearing intervals that are encountered will be noted and isolated. (12) the duration of the disposal operation, not to exceed 90 days; The duration of the disposal operations will be no more than 90 days during the 1 year period for which the annular disposal permit is valid. ( 13) whether drilling waste has previously been disposed of in the annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated; The proposed well is a new well. No annular injection has been undertaken in this area. 14) the well where the drilling waste to be disposed of was or will be generated; The drilling waste to be disposed of will originate from the referenced Hansen No.1, No.2, or one of the sidetrack operations if that becomes necessary. The surface location of the well is in the NW/4 Sec 2-T4S-RI5W S.M. Alaska The proposed wellbore trajectory places the 13 3/8" surface casing shoe (disposal point) approximately 5,155' west northwest ( 299 0 Azimuth ), which will be 4,500' from the shoreline. (15) if the operator proposes not to comply with a limitation established in (d) of this section, an explanation of why compliance would be imprudent; The volumetric and time limits set forth in section (d) appear to be adequate for the Hanson project. A very slight show of gas was recorded in the Starichkof State No.1. This zone was DST'd as DST No. 10 March 25, 1967. It had a slight gas show, too small to measure. The other two offsets in the vicinity (Starichkof Unit No.1 and the Anchor Point No.1) had no shows and the correlative sands logged wet. There are no other oil or gas wells located within % mile of the site. ( 16) any additional data required by the commission to confirm containment of drilling waste. An attached memo from Wayne Campaign describes the method used to calculate the TDS of the formation. Thank you for your assistance in processing this authorization. If you have any questions or additional data needs, please do not hesitate to contact me at 263-4603. Sincerely, rJ. fYl~ Paul Mazzolini Exploration Drilling Team Leader Page 5 of 5 OHILtuvAL ) ') II PHILLIPS Alaska, Inc. A Subsidial'Y of PHIlLiPS PETROLEUM COMPANY To: Bob Swenson Subject: Wayne Campaign 265-1505 Shallow Salinities for the Cosmo Project Area. May 10, 2001 From: Date: This memo will discuss the issue of shallow salinities in the Cook Inlet as they pertain to the Cosmo project. We will present salinity information from the closest offset (Anchor Point #1), calculated in a manner consistent with the techniques laid out in the EP A document. Two methods are used in this evaluation. The "Rw Apparent" (Rwa) method re-writes the Archie equation: Ro = a*Rw/cpm and solves for Rw. The assumptions are; the sand is 100% water bearing (that is the implication of the term Ro to represent the sand resistivity), and no excess conductivity (shale) in the system. Porosity (CP) is derived from the sonic, as it is most common in these older wells. For sonic porosity, I use an adaptation of the "Hunt-Raymer" algorithm 1. cp = 0.6* (AT-56) /AT We verify this algorithm by comparing to core porosity in the Starichkof Unit #1 (fig. 1). Other assumptions include values for a and m (cementation exponent). The EPA document uses the Humble formulation (a = 0.62 and m = 2.15), and I have used that here. I use a temperature gradient of 1.3° F/100 ft. + 450 F mean annual surface temperature. I have converted all water resistivities to 75°F for easier comparison, and calculated salinities in kppm, Total Dissolved Solids. Rwa has also been calculated in the shales. Porosities will be overestimated and mineral conductivity will be a factor, but these are opposing effects and the result will still be at least a qualitative measure of the fluid properties. The second technique uses the Spontaneous Potential (SP) curve. This curve measures the electric potential created by salinity contrasts between invading mud filtrate and connate water. Bounding shales serve as semi-permeable membranes, which enhance the reaction. Other effects on the SP are shale content of the sand, sand permeability and thickness, invasion, hydrocarbon content, and the ions in solution. In fluvial sections that are charged with original water, there are significant concentrations of bicarbonate (HC03 -). This ion has a different mobility than those assumed within the SP calculation. Empirical charts are available that attempt to correct SP for these and other effects, but I have used the SP directly. One further issue with the SP is that it often will wander, especially in these shallow sections. To straighten, or "baseline" the SP curve is a standard procedure, though may be somewhat subjective in extreme cases. These problems are difficult to overcome so I have not put much credence in the SP evaluation in the fluvial sections. Continuous water resistivity and salinity curves have been calculated for Anchor Point to a depth of 7500'. Sands with maximum SP excursions have been calculated with the SP technique as a check. 0.= 'G,NAL Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company Mr. Wayne Campaign May 25, 2001 Page 2 ) ) Conclusions: Evaluation of the Anchor Point offset well show salinity to be less than 500 ppm Total Dissolved Solids above a depth of 200 feet. From 300' to 3400', TDS calculates at 2200 ppm. Salinities in the interval 3500' to 6500' are 4000 ppm. Care must be taken through this section to recognize the gassy and coaly sands. These give erroneous porosity estimates which skew the Rwa results. These sands are coded red on figure 2. Below 6800', salinity rapidly increases to 16000+ ppm TDS. The SP is of little help in the section above 7000', but is much more comparable below. In Anchor Point, the particular sand of interest is presented as figure 3 . Average TDS value within this sand is 4000 ppm. This is the corelative sand to our proposed annular injection interval. If you have any questions, feel free to contact me. Wayne Campaign PAl Petrophysicist Porosity: Core .vs. Sonic Well: Starichkof Unit #1 :::: :~~:~~r~~~~:--=·~~~==\:=~-_:=~::J~-~t~=:~ ~ 0.21 "·····,,""····".."1'·····"......,..······ ..,..""'.-."""".-"."'...'''.....,.j,''.....,...'''......····..!··""·,·..·"t..,·"",,..," ¡ ".""!........"j.,""..",","".....¡,.""..."...""..,, :> I ) · I ! i 0.18 ------1:------.--:--~-t-:-!¡¡ ". J',. ~¡-------I,····"··..·"······,·· ~ 0.15 --1--- i I~-+:- -~ - r. -1------¡--·-··- ~ :·::~J-==t~I-=~:~:t-~t:I=t:=I-:::: . .1 I I I I: j l ! O 0 6 ____.__J.---.-.. ~ ··-·_..··!"l!_~-·..···l..................J...._._"...].....,_.._.J........_. ..-..l.--...-.j............-.... . : I '\! ¡ \ ¡ I : .'1 ' : ¡ i ' ¡ I 1 I : : i i : i i 0.03 .......,_.,,_._, ._.m-·-..···1-_··_...._·]····_·_·,··..i...._....··....··~····..··-·..·····¡-"..·..---l·"··"-·....···r····-·-··'['·-..·..-·-· ¡ 0.00 C! c C! CO) o cO c ø) c N ..... c u) ..... c cõ .... C! ..... N c ~ N C! " N o Q CO) CORE Porosity (PCT) Figure 1. This figure compares the porosity generated from the sonic with core data from the Starichkof Unit well. This validates the sonic porosity algorithm used in the Rwa technique. Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company \.¡' . M ~ \¡¡¡,1'~ ¡;¡ . Iii i Ii iiiäw Mr. Wayne Campaign May 25,2001 Page 3 .-. "()()(' I- .) ..1 W W '~").) LL ,,~)\.I. ......... ::I: I- ,1000 a.. W C 4500 ) ) TDS I DEPTH Cross plot Well: ANCHOR_PT_1 Filter: SBL<-20&COAL==MISSING&DT>80 o ~)oo woo 1500 i'l _,.'¡I:j1i -. -:t: :tli~'. .._ , II! Ii '..:,lli~. -~ ¡. ii' II -'Iii, I! 2000 2~)O() ~)(')OO . Sand of Interest E)(j 00 Coaly, Çìas:sy I Interval:. Y /P Calculations -. . \ -":-~~_" ".1.... .:.:..:- "--~~.t"': - i~' I c c c c c c cc cØ a:i 0 ~ .. cØ a:i 0 ,... ..... ..... ,... ..... C'I GOOCi 6500 "/000 7500 c o c ~ c .. Total Dissolved Solids (Kppm) -- Color: GAS_SHOW Figure 2. This is a plot of TDS values calculated from the Rwa technique, versus measured depth of the Anchor Point # 1 well. The data has been filtered to eliminate coals, tight streaks and shales. Intervals that correlate with gas shows from the Mudlog have been coded red. SP calculations are the red ovals and show poor correlation until salinities exceed 1 ??oo ppm. The scatter at the bottom of the plot is due to thin, low quality, low porosity sands. Phillips Alaska, Inc. is a Subsidiary of Phillips Petroleum Company Vi. , ~J Ii ¡J~ ii J.. Mr. Wayne Campaign May 25, 2001 Page 4 ) ) ANCHOR PT. #1 I I I~'~ 1 i 3800 ..:=.. 1 II '-L I i II I I I I I! ¡ l ~ .. I Ci I) r'll \/ o TDS KPPM 171 i~'_ I~ _-'v- I ,.... 1< I <.,. I~ I--:? ILD DT I) DEPTH l' - - - -OHtl~M - - - 10õ1'5õ - - - - - - 1j'S OF - - - - - - -:0 FEET SN_ES_S_1 III C;()/\L....2111111i 10 r 1) ;¡ii' \,' OHM M 100 F' C:T II I [ I ~. ° ~ I~ ~I II I .. ~~ ! 'l ~ "",jl ~verage TDS = 4 Kpprñ' "" 370.... ~) JI 1IIIP""" I I 11 I I II I .( II . I I i J. ':r,' .....~:I.r~f~'?··~'~¡;.~:¡'~~rþ~2.~jil, . ":1 ' 1,1, . ... ' ·.~I~J·r"..,~ . '11:~t',' 1,1,'.., .',.. ..... .' '~',I.,;: .' , ~." I.. .,.'..:.... ..,1 . II,", ..1,\,\,.11 ,'I :·:\1111 :. ~. :,11' ":. I ..~~I ",,>,: ::'. .",':I~!'I.,I ,1"';1 >,·.""~'1.,,,.!, :".t!.>.':.:, ':"'\';" :,!:.'.:. i.".'~:'·:~'I' >:",11:\ ': 'I '...' I· .1' .:1· ..111 ,.··..1., ...,' ,. .1·1 ,"" . 1·1" , ... ·:·il, . I' U .. ." ' :. '.",.".,', :1.:, 'I I.I-"':¡" I ,. ~ I .-.1:"--- "' ~ " 1. ,,'"' r'-'. --- ~ 'I 1 -~~. f,~" -I ~,r_~L I Ii' -=-1. .. I I:':~J PI] ..~ . t--.:.. ":10 II ......I~- I ......... II' --~ _..~ I I I - Jþo '1 I i I lit II:' i! III I II ~;- ..:- +- "!IOo I J.-.;- , '.... I I ........ I~I -r-- I ...... ......,..- -1":.:. II .....;.-~ : J , f¡ ! - "t_ ............'...1. ~ -- ~1- I ! - ....-- I ~ !(' ~;Il. ~ < J Figure 3. This is the correlative sand for injection. Porosity is just over 25% and the TDS of the conate water is 4000 ppm. Phillips Alaska, Inc. Is a Subsidiary of Phillips Petroleum Company UHluJiVAL ) ft . ¥ ~: ",.,'·,1' 'r~', .' American ExpressQi) Cash Advance Draft 152 . . . DATE 20 ,1u-~ 2eo I .,-"",ro, ~~YD:~~~E·· ~k Æ. /UL~ft- / /ÎOqCL . I $1 ¡oo.O() _____ O)-<.e JLÞz-..Þ-f;l··fu.,rc; þl--J ~ !~;!> 0=, DOLLARS Issued by Integrated Payment System, Inc. Enzlewood.Colorado N~O. TV.. ID FOR~MO ..N..J VER$IOOO .....' Payable at Norwest Bank of Grand Junction - Downtown, NA . HARON SUpm Grand Junction, Colorado .I,i? -/ /k. ~... . /' '/.ð PERIOD ENDINFI ..lL: I I - I~ .--.' . ~ rIa t1.s tN!' I: ~ 0 2 ~ DOL. 0 0 I: :. 5 II. 0 ~ ? 5 000 5 :U; III 0 ~ 5 2 '" ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~1 ~'"L -:/Þ / CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORA7 INJECTION .WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last· two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <->NO ANNULAR D"OSAL <vb YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ---'---' Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. 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 number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. 4~¿4"- WELL PERMIT CHECKLIST COMPANY -fì- J // ~ WELL NAM~ ~ I PROGRAM: exp ,/ dev ~ rednl_ serv _ well bore seg _ann. disposal para req _ FIELD & POOL /1/ A INIT CLASS E;(.f> (0,1) GEOL AREA 87£; UNIT# A/ rl ON/OFF SHORE 0'1 ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . ......- ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . 'Ò N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . ® 5. Well located proper distance from drilling unit boundary. ~ N 6. Well located proper distance from other wells.. . . . . . . . . Y' N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbore plat included.. . . . . . . . . . . ... . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . "N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Pennit can be issued without conservation order. . . . . . . . " N ~.~~ DATE 12. Pennit can·be issued without administrative approval.. . . . . N p b V 7 r 31,(,,") ( 13. Can permit be approved before 15-day wait.. . . . . . . . ". Y.y) N , 10. r h _ _ è't.\'":>~/ , ~ ~ _ . . (\ Æ.. . f>~"'~~,......~~~.~~""'-~"t.~~~~~~~~~ ENGINEERING 14. Conductor string provided .. . . . . . . .. . . . . . . . .. l& N 1"_. 11b. / / I . / / \. 15. Surface casing protects all known USDW~ .. . . . . . . . . )N .:f-~eA.so~ 4.h ~. ~-r-<"T, 3~b3 ?,ý.l), ¿~ a..Jo"\qt~S¡~ ~. 16. CMT vol adequate to circulate on conductor & surf csg. . . . . . N~'¡ ~j{ /J¥,C-lLLe>-V' P¿". #1 (,.,c!r.:yt-!e..$ ~'l~lírJ G¿f(/q..f -Itù5 17. CMT vol adequate to tie-in long string to surf csg. . . .' . . . . y ~~t1 fV. i /1 ro-/-Lc!..1- a./ I ~ulJl..r5 ún ..¡-¡( -á q/~ ;1/& c::: 3éÞc:.~ r '7ì>S ." . 18. CMT will cover all known productive horizons. . . . . .. . . . . ~y - , 4D 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N ., 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~Ec. "'C3...~~~~<;) d-\~~ C:;~\~,I ~\~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . .y t4 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations . . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate; test to '2...,'C'Ot.J psig. N . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdöwn. . . . . . . . . . .Ji~ 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . y \tiJ 3D. Permit can be issued WiD hydrogen sulfide measures. . . .. '$ :.::,..:> "".,......,..;~,~; <¡ 4 vi:, ,'/A./...<-, f tv>.1/ &- ~.. 4kl1 ¿,.hI ( k 31. Data presented on potential overpressure zones*. . . . . . N ;nu:-,,¡(~~ ~ ¿!su./J-~~a...<!.;':1ð ~ 'If).. . 32. seismicanal~~isofshaIlO~gaszones~. . . . . . . . . . . . ~t~/~ A_A..S':~s ~q,4J~/> t-Vtd'/&7-k.-g a. /1C;>rnv¿(~""¿4?U1< f1f"4d':¿¡1:f.. AP~ DATE I 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . #A . - ob þ¡;,u¿ÞJ5eJ.?L bf. Ff' /1e¡p~Or-~ ~fltr- ~H:-I<J¿,...e.,.. 1\6f ¿¡'\c/¡~t:f-h~ S ~ ~I ) 7. 31-0 .34. Contact name/phone for weekly progress reports [exploratory onlyr:Þ N c4/....~. ./Iò tU 'X't. ~ , ~ V I ~ ¡bl-r:- ;.,., -H~.54~ P111 t-,. ~. ... .. -/..t -5 ed æl,. &~ -/-t.J-. ¿'.';)l..<...r-~ d- . ., '-- -7tds toN/. 41> 7'51-01. ~ . g \,. ~ ANNULAR DISPOSAL35. With proper cementing records, this plan. 73;/1 i-/ô;, <Í < ....I_Ç' h$""3 ( ~"~~\<9-,"~,'":>~~\ ~ ~ ~~ ~ \.~ ~~t)'f.c...ð (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (J . ~ ~" ~. \ ,\ (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:.· UIC/Annular COMMISSION: ~¡;~~ ~~, ~ WM8~s -¡ Jj? Þ . ~ ./Jþ;- T'Ë~G/{ JMH p:;fM'bt/ Qlv51ót ~ ~J}TE . rq;~11 { l'l GEOLOGY APPR DATE Comments/lnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c o z o -I ~ ::0 -I. m ( -. Z -I J: en :Þ ::0 m » / '\
