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Home My WebLink AboutERIO 004 e e Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Order File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 11111111I111111111I RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner o Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: D Other:: BY: ~ Date: J J. '" If I fJ ~ I I /s/ t11E 1111111111111111111 ~ 5'ö Project Proofing BY: ~ Date: J ~11'f / Db , I /s/ Scanning Preparation BY: Date: 11111111I111111111I = + = TOTAL PAGES (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ Date:/d-Jtc.rJO~ If NO in stage 1, page(s) discrepancies were found: YES NO /s/ (Y\ P Stage 1 BY: NO BY: Maria Date: /s/ III 11111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111I 1111111 10/6/2005 Orders File Cover Page. doc . . INDEX Enhanced Recovery Injection Order #4 Colville River Unit Qannik Reservoir 1. October 20, 2006 ConocoPhillips Approval of Pilot Injection in the Qannik Reservoir Notice of Hearing, affidavit of mailing, e-mail list, bulk mailing list 2.0ctober 23,2006 Enhanced Recovery Injection Order #4 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF CONOCOPHILLIPS ALASKA, INC. for an order authorizing a pilot injection project designed to test the potential for enhanced oil recovery in the Qannik Accumulation, Colville River Unit, North Slope, Alaska ) Enhanced Recovery Injection Order No.4 ) ) Colville River Unit ) Qannik Accumulation ) Well Colville River Unit CD2-404 ) December 11, 2006 ORDER CLOSING DOCKET BY THE COMMISSION: The Commission has the closed the Docket in the above captioned matter. DATED AND EFFECTIVE at Anchorage, Alaska and this 11th day of December, 2006. BY DIRECTION OF THE COMMISSION . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF CONOCOPHILLIPS ALASKA, INC. for an order authorizing a pilot injection project designed to test the potential for enhanced oil recovery in the Qannik Accumulation, Colville River Unit, North Slope, Alaska IT APPEARING THAT: ) Enhanced Recovery Injection Order No.4 ) ) Colville River Unit ) Qannik Accumulation ) Well Colville River Unit CD2-404 ) ) December 11, 2006 1. By letter and application dated October 20, 2006, ConocoPhillips Alaska, Inc. ("ConocoPhillips") as Operator of the Colville River Unit ("CRU") requests an order from the Alaska Oil and Gas Conservation Commission ("Commission") to authorize pilot water injection into well Colville River Unit CD2-404 ("CD2-404") to test the potential for enhanced oil recovery under 20 AAC 25.402. 2. Notice of a public hearing was published in the Anchorage Daily News on October 23, 2006. 3. No comments, protests or request for public hearing were received. 4. The Commission determined it had sufficient information as a basis for ruling, and the tentative public hearing was vacated. FINDINGS: 1. Operator: ConocoPhillips is operator of the Qannik Accumulation ("Qannik") in the CRU, North Slope, Alaska. 2. Proiect Location: The surface location of well CD2-404 is 1,605' from the north line and 1,559' from the east line of Section 2, TIIN, R4E of the Umiat Meridian. The bottomhole location is 956' from the south line and 928' from the west line of Section 26, TI2N, and R4E of the Umiat Meridian. The surface and bottomhole locations are located onshore within the CRU. Enhanced Recovery Injectionler No. 43 December 1, 2006 . Page 2 3. Operators/Surface Owners Notification: ConocoPhillips provided operators and surface owners within one-quarter mile of the proposed area with a copy of the application for injection. The only affected operator is ConocoPhillips. The Kuukpik Corporation is the only affected surface owner. 4. Description of Operation: The Qannik is a potentially productive interval that has been penetrated by many wells targeting the deeper defined pools within the CRU. Well CD2-404 is the first well drilled to specifically target the Qannik. ConocoPhillips conducted flow tests on CD2- 404 and now proposes to conduct injectivity tests using seawater to further evaluate the commercial potential of the Qannik. ConocoPhillips' proposed project involves injecting up to 30,000 barrels of seawater at various rates to determine fluid compatibility and fracture initiation pressure and then to flowback the injected water to evaluate sand control issues for future producing wells after water breakthrough. 5. Geologic Information: a. Injection will occur within CD2-404 into the Qannik, which is currently not part of a defined pool. The application describes the Qannik as the accumulation of hydrocarbons that is common to and correlates with the accumulation found in well Colville River Unit CD2-11 between the measured depths of 6,084' and 6,253' (4,013' to 4,099' true vertical depth subsea). b. The Late Cretaceous aged Qannik represents a Brookian topset play in which thin shallow marine sands (5 to 25 feet gross sand) are trapped stratigraphically and structurally. 6. Well Logs: The initial formation logs obtained while drilling well CD2-404 are on file with the Commission. 7. Mechanical Integrity and Well Design ofIniection Wells: Well CD2-404 was permitted as an exploratory well in accordance with 20 AAC 25.005. ConocoPhillips anticipated possible use of the well as an injection well and designed it to meet those requirements. The drilling and cementing records fÌ'om CD2-404 were reviewed and found satisfactory to prevent the wellbore fÌ'om serving as a conduit for fluid migration out of the approved interval. 8. Iniection Rates. Pressures. Fracture Propagation: The injection rates are expected to average 1,500 to 3,200 barrels water per day ("BWPD"). The injection rate will be managed based on a step rate test used to determine fÌ'acture initiation pressure. 9. Type of Fluid / Source Water Analysis: The fluid requested for injection is seawater provided from the Alpine Central Facility. Compatibility of the seawater and the Qannik is unknown and is a major factor for conducting the proposed test. Enhanced Recovery Injection ler No. 43 December 1,2006 . Page 3 10. Freshwater Information: Area Injection Order 18B concluded no underground sources of drinking water exist below the permafrost in the CRU area. 11. Expected Increase in Hydrocarbon Recovery: There is no incremental hydrocarbon recovery associated with this proposed project. This project is intended to determine if a water flood will enhance recovery, and determine the critical design considerations for a full scale EOR project. 12. Mechanical Condition of Adiacent Wells: Six Alpine Oil Pool development wells lie within the 1f.t mile area of review ("AOR") for CD2-404. Four of the wells are within If,¡ mile of the 7-5/8" production-casing shoe with the remaining 2 wells within the AOR along the well's trajectory. None of these wells is cemented across the Qannik. CP AI has not reported any problems with any of these wells. CONCLUSIONS: 1. The application requirements of20 AAC 25.402 have been met. 2. A review of the well records indicates that CD2-404 is constructed in a way that will prevent the migration of fluids outside the Qannik. Well integrity for CD2-404 must be demonstrated according to 20 AAC 25.412 (c). 3. Six wells penetrate the Qannik formation within 1f.t mile of well CD2-404 targeting deeper productive formations. In each well, the production casing is uncemented across the Qannik. The volume of seawater to be injected represents a zone of influence within the Qannik that is insufficient to reach any of the 6 adjacent wells. Monitoring of the open annuli pressures in wells CD2-03, CD2-09, CD2-11; CD2-12, CD2-15, and CD2-23 will be used to ensure no fluids migrate out of zone via the uncemented annuli of these adjacent wells. 4. The suitability of seawater injection has not been established for the Qannik. 5. There are no potential sources of underground drinking water beneath the permafrost in the CRU area. 6. Sufficient information has been provided to authorize pilot water injection into the Qannik to evaluate the suitability of seawater injection as a possible enhanced recovery technique. 7. Injection pressure will be monitored to evaluate fracture initiation, propagation, and leak-off properties of the injectant. 8. Injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the wellbore and appropriate operating conditions. 9. Well surveillance will help demonstrate the performance of the pilot injection project or disclose possible abnormalities. Enhanced Recovery Injectionler No. 43 December 1, 2006 . Page 4 NOW, THEREFORE, IT IS ORDERED THAT: The underground injection of water for the evaluation of enhanced oil recovery is authorized in CD2-404, subject to the following rules and the statewide requirements under 20 AAC Chapter 25 to the extent not superseded by these rules. Rule 1: Expiration Date This Order shall expire 12 months after its effective date. Rule 2: Authorized Injection Strata Injection into the Qannik accumulation is authorized. The Qannik accumulation is the accumulation of hydrocarbons that is common to and correlates with the accumulation found in well Colville River Unit CD2-11 between the measured depths of 6,084' and 6,253' (4,013' to 4,099' true vertical depth subsea). Rule 3: Fluid Injection Well Well CD2-404 is the only well authorized for fluid injection during this pilot project. Rule 4: Authorized Fluid for Enhanced Recovery No more than 30,000 barrels of seawater may be injected. Seawater received from the Alpine Central Facility is the only fluid authorized for injection during this pilot project. Rule 5: Authorized Injection Pressure for Enhanced Recovery a. After determination of the fracture initiation pressure by means of a step rate test the normal injection pressures must be maintained below the parting pressure of the Qannik. b. Injection pressures must be maintained so that injected fluids do not fracture the confining zone or migrate out of the approved injection stratum. Rule 6: Demonstration of Tubin2/Casin2 Annulus Mechanical Inte2rity The mechanical integrity of the injection well must be demonstrated before injection begins, and before returning the well to service following a workover affecting mechanical integrity. A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in the well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 2500 psi, that shows stabilizing pressure and does not change more than 10 percent during a 30-minute period. Results of mechanical integrity tests must be submitted to the Commission upon completion. Enhanced Recovery Injectionler No. 43 December 1, 2006 . Page 5 Rule 7: Pilot Project Surveillance Information gathered from the pilot, including daily wellhead injection pressures, tubing and casing annuli pressures in all wells within ~ mile of CD2-404 injection interval that have uncemented penetrations through the Qannik, injection rates, volumes injected and produced back, and injection test results shall be monitored and provided monthly to the Commission until the pilot project is completed. At the conclusion of this pilot EOR project[Tlo], a report shall be sent to the Commission containing information regarding project parameters including but not limited to: a. Compatibility of seawater with Qannik formation fluids. b. Analysis of injection performance. c. Analysis of fluid containment surveys, step-rate tests or MIT's that would demonstrate confinement of injected fluids. d. Evaluation of fracture initiation, propagation, and leak-off properties determined from the pilot project. e. Evaluation of annular pressures in the following adjacent wells: CD2-03, CD2-09, CD2-11, CD2-12, CD2-15, and CD2-23 f. Review of any specialized tests performed to gauge performance and results of the pilot project. Rule 8: Notification of Improper Class II Injection Injection of fluids other than seawater is considered improper Class II injection. Upon discovery of such an event, the operator must immediately suspend injection, notify the Commission, and provide details of the operation. Additional notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 9: Well Inte2rity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. Rule 10: Other Conditions It is a condition of this authorization that the operator complies with all applicable Commission regulations. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Enhanced Recovery Injectionler No. 43 December 1, 2006 Rule 11 Administrative Actions . Page 6 Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. DONE at Anchorage, Alaska and dated December 11, 2006. ~ Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission f/ Cathy P. F erster, Commissioner Alaska Oi and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it Month file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23'd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days ITom the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by non- action of the Commission, the 30-day period for appeal to Superior Court runs ITom the date on which the request is deemed denied (i.e., 101b day after the application for rehearing was filed). WO)'ÁeMa'MMM pue wO)'ssaJdX3a¡eJodJo)'MMM (6Z£9'S£Z) Á'v'OO.L 3J'SSS'L Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 . George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise,lD 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 80ZEOE>3j a.¡e/dwa.¡ aSn David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 James Gibbs PO Box 1597 Soldotna, AK 99669 Richard Wagner PO Box 60868 Fairbanks, AK 99706 North Slope Borough PO Box 69 Barrow, AK 99723 . I ms'šãJd;3 ~ 3 11 n ! v N !) I 5 a~eJodJo:>v Mona Dickens Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Ivan Gillian 9649 Musket Bell Cr.#5 Anchorage, AK 99507 Jack Hakkila PO Box 190083 Anchorage, AK 99519 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 y\ ¡j,lI.J:D \ ()\D \ro\ \r;I\ :J.OOJd-Wer saqel 6u!l!ell'J JaSel Colville River Unit Qannik Reservoir ERIO #4 . . Subjeçt: Colville River Unit Qannik Reservoir ERIO #4 From: Ceresa Tolley <ceresa_tolley@admin.state.ak.us> Date: Wed, 13 Dee 200609:44:38 -0900 lof2 12/13/20069:45 AM Colville River Unit Qannik Reservoir ERIO #4 . . 20f2 12/13/20069:45 AM :#;1 I STATE OF ALASKA .. NOTICE TO PUBLlSHE'M ADVERTISING ORDER NO. , ADVERTISING INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO.. CERTIFIED AO-02714010 AFFIDAVIT OF PUBLICATION (PART2 OF THIS FORM) WITH ATTACHED COPY OF ORDER ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ,)EE BOTTOM FOR INVOICE ADDRESS . AOGCC AGENCY CONTACT DATE OF A.O. R 333 W 7th Ave, Ste 100 Jodv Colombie October 20 2006 0 Anchorage, AK 99501 PHONE PCN M - (Q07) 7Q~ -1 )') 1 DATES ADVERTISEMENT REQUIRED: T Anchorage Daily News October 23,2006 0 THE MATERIAL BETWEEN THE DOUBLE LINES M1.:ST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. -. - + - - - SPECIAL INSTRUCTIONS: Advertisement to be published was e-mailed Type of Advertisement LegalIS! D Display Classified DOther (Specify) SEE A TT ACHED SEND INVOICE IN TRIPLICATE I AOGCC, 333 W. 7th Ave., Suite 100 1 TOTALOF ;1 PAGE 1 OF ALL PAGES$ TO Anchorage AK 99501 2 PAGES REF TYPE NUMBER AMOUNT DATE COMMENTS 1 VEN 2 ARD 02910 3 4 FIN AMOUNT SY CC PGM LC ACCT FY NMR DIST LiQ 1 05 02140100 73451 2 I .. REQ¡ÙISI~[tÜ BY; DIVISION APPROVAL: f',,_/H)I "vj i~ \ J ~ ¡¡ '\ .j / '-" ~..,,=~ . . / ----- . '--...... Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Colville River Unit Qannik Accumulation Application for Enhanced Recovery Operations (Pilot Waterflood Project) By application dated October 20, 2006, ConocoPhillips Alaska, Inc. ('~ConocoPhillips") as Unit Operator of the Colville River Unit requested the Commission to approve Enhanced Recovery Operations to authorize a pilot waterflood project in the Qannik Accumulation. ConocoPhillips proposes to inject seawater into the Qannik Accumulation with the CD2-404 well with a surface location in Section 2 TIIN-R4E Umiat Meridian and a bottomhole location in Section 26 T 12N-R4E Umiat Meridian. The Commission has tentatively scheduled a public hearing on this application for November 28, 2006 at 9:00 am following a previously scheduled meeting at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th 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 no later than 4:30 pm on November 8~ 2006. If a request for a hearing is not timely filed, the Commission may consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 after November 14,2006. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska Oil and Gas Conservation Commission at 333 West ih A venue, Suite 100, Anchorage, Alaska 99501. Protests and comments must be received no later than 4:30 pm on November 22, 2006 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the November 28, 2006 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact the Commission's Special Assistant lody Colombie at 793-1221 before November 24, 2006. ~~ Commissioner Published Date: Anchorage Daily News 10/23/2006 AO # ADN 02714010 10;1~1200ö ~-~. ----.=-~.,-...ç~ Anchorage Daily News Affidavit of Publication 1001 Northway Drive. Anchorage, AK 99508 GRAND TOTAL OTHER CHARGES #5 OTHER CHARGES #4 OTHER CHARGES #3 OTHER CHARGES #2 OTHER CHARGES Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: Colville River Unit Qannik Accumulation Application for Enhanced Recovery Operations (Pilot Waterflood Project) By application dated October 20, 2006, ConocoPhil- lips Alaska, Inc. ("ConocoPhillips") as Unit Opera- tor of the Colville River Unit requested the Com- mission to approve Enhanced Recovery Operations to authorize a pilot waterflood project in tne Qan- nik Accumuration.CcinocoPhillips proposes to in- ject seawater into the Qannik Accumulation with the CD2-404 well with a surface location in Section 2 T11 N-R4E Umiat Meridian and a bottom hole 10- I cation in section 26 T12N-R4E Umiat Meridian. The Commission has tentativelY scheduled a pub- lic hearing on this application for November 28, 2006 at 9:00 am following a previously scheduled meeting at the offices of the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage,Alaska 99501. Aperson may request that the tentativelY scheduled hearing be held by filing a written request w4th the Commis- sion no later than 4:30 pm on November 8, 2006. I I f a request for a hearing is not timely filed,. the Commission may consider the issuance of an or- der without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221 af- ter November 14, 2006. In addition, a person may submit a written protest or written comments regarding this application and proposal to the Alaska oil and Gas Conserva- tion Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. Protests and comments- must be received no later than 4:30 pm on Novem- ber 22, 2006 except that if the Commission decides to hold a public hearing, protests or comments must be received no later than the conclusion of the November 28, 2006 hearing. If you are a person with a disability who may need special accommodations in order to comment or to attend the public hearing, please contact the Commission's Special Assistant Jody Colombie at 793-1221 before November, 24, 2006. Is/: Cathy P. Foerster Commissioner AO# ADN 02714010 Publish: October 23, 2006 -- -- - -c- $189.60 $0.00 $0.00 $0.00 $0.00 $0.00 PRICE PER DAY $189.60 $189.60 ACCOUNT STOF0330 STATE OF ALASKA THIRD JUDICIAL DISTRICT PO 02714010 DATE 10/23/2006 AD# 16783 Christine Clark, 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 during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published 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 foregoing publication is not in excess of the rate charged private individu/j Ii Signe to me before this date: for the State of Alaska. Alaska \\{{((((({ffl. ~~tlL y 4. .;:"1'"1"': ..' .:.~:... .~~ ~: ",OTARj:~.L~ . sßtea: - ~ ::: : ÞUÐ~.}C : ~ - ~ . - - -' .f¡;: :::,.::e. . ~ ... ... fa E· - ~ ~a ·.7.þ, ~~. ~ .~9:~ . ,~Of ¡t.,\'> JJ.':V 'l" _. :,' . , >~p", /,1;, rJ;¡ O:p¡¡~fÚ" . \" , .//l1)Jj))i\\' Notary Public in and Third Division. Anchorage, 02-902 (Rev. 3/94) ~. .' _-. ..J Publishefitjriginal Copies: Department Fiscal, Departmëiir, Receiving AO.FRM r STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS NOTICE TO PUBLISHER ADVERTISING ORDER NO. 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-02714010 F AOGCC 333 West th Avenue. Suite 100 A nch()r~ge. A K 99S0 1 907-793-1221 AGENCY CONTACT Tnrlv Cn1.11 ¡1-,;r- PHONE (907) 791 -1 ?? 1 DA TES ADVERTISEMENT REQURED: DATE OF A.O. R o \1 0, ·í.lhr-" ?O ?OOlí PCN T o Anchorage Daily News October 23,2006 THE MATERIAL BETIVEEN THE DOt:BLE Llì'ìES MUST BE PR[:\TED [;.i ITS E~TIRETY ON THE DATES SHOWN. SPECIAL [NSTRUCTIOì'ìS: Advertisement to be published \vas e-mailed United states of America I State of I AFFIDAVIT OF PUBLICATION REMINDER 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. ore 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 2006, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2006, 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 2006, . 'Îtary public for state of ¡ commission expires ~1 "--- --..-- RECEIVED OCT 2 0 2006 Alaska Oil & Gas Cons. Commission Anchorage Application to the Alaska Oil and Gas Conservation Commission for Approval of Pilot Injection in the Qannik Reservoir Colville River Unit ConocoPhillips Alaska, Inc Anadarko Petroleum Corporation October 20, 2006 Application to the AOGCC for J\.'pProval of Pilot Water Injection into the Qannik Reservoir Colville River Unit '- Table of Contents Introduction......................................................................................................................................... .........................3 20 MC 25.402 (c)(1) Plat of Wells Penetrating Injection Zone...........................................................................4 20 MC 25.402 (c)(2) Operators and Surface Owners within One Quarter Mile of Injection Operations...... 5 20 MC 25.402 (c)(3) Affidavit of Tim W. Crumrine Regarding Notice to Surface Owners............................. 6 20 MC 25.402 (c)(4) Description of the Proposed Operation............................................................................. 7 20 MC 25.402 (c)(5) Description and Depth of Pool to be Affected .................................................................. 8 20 MC 25.402 (c )(6) Description of the Formation .............................. ................................................................9 20 MC 25.402 (c )(7) Logs of the Injection Wells ............ .......... ........... ...... ................ ................... ....... ............... 13 20 MC 25.402 (c)(8) Casing Description and Proposed Method for Testing .................................................14 20 MC 25.402 (c)(9) Injection Fluid Analysis and Injection Rates................................................................... 15 20 MC 25.402 (c)(1 0) Estimated Pressures .......................................................................................................16 20 MC 25.402 (c)(11) Fracture Information ........................................................................................................17 20 MC 25.402 (c)(12) Quality of Formation Water.............................................................................................18 20 MC 25.402 (c)( 13) Aqu ifer Exem ption Reference........ ....... ................................... .................. ...... .............. 19 20 MC 25.402 (c)(14) Incremental Hydrocarbon Recovery..............................................................................20 List of Fiaures Figure 1 Proposed Affected Area for Qannik ...................................................................................................... 22 Figure 2 ~ Mile CirclelTangent with Existing CD2-404 Well and Alpine - Qannik Penetrations. ...............23 Figure 3 Proposed Qannik Field Development........................ ............. .................. .................. .......... ................24 Figure 4 CD2-404 Injector Well Schematic.......................................................................................................... 25 Attachments Well bore and Near Well bore Reservoir Pressure Modeling Bergschrund 1 Log CD2-03 Well Completion Report (AOGCC Form 10-407) CD2-03 Well Schematic CD2-09 Well Completion Report (AOGCC Form 10-407) CD2-09 Well Schematic CD2-11 Well Completion Report (AOGCC Form 10-407) CD2-11 Well Schematic CD2-12 Well Completion Report (AOGCC Form 10-407) CD2-12 Well Schematic CD2-15 Well Completion Report (AOGCC Form 10-407) CD2-15 Well Schematic CD2-21 Well Completion Report (AOGCC Form 10-407) CD2-21 Well Schematic CD2-23 Well Completion Report (AOGCC Form 10-407) CD2-23 Well Schematic Page 2 ConocoPhillips Alaska, Inc. Application to the AOGCC for Xpproval of Pilot Water Injection into the Qannik Reservoir Colville River Unit ""-' Introduction This application to the Alaska Oil and Gas Conservation Commission (AOGCC) seeks endorsement and authorization for the Qannik CD2-404 proposed pilot water injection in the Colville River Unit (CRU), by asking for a variance to underground injection control and hence the Area Injection Order listed on the Permit to Drill (Number 206-054) under Article 20 AAC 25.450 Section (a) as the injection will not occur into, through, or above freshwater as evidenced by conclusion (3) of Alpine Area Injection Order 18A; and Article 20 AAC 25.450 Section (b) as a pilot project for enhanced oil recovery using a technology not proved feasible under the conditions in which it is being tested. While still seeking a variance, this application for pilot injection approval has been prepared in accordance with 20 AAC 25.402 (Enhanced Recovery Operations) and 20 AAC 25.460 (Area Injection Orders). This project involves injecting 15,000 to 30,000 barrels of Beaufort seawater into the Qannik reservoir (defined in section 20 AAC 25.402 (c)(5) Description and Depth of Pool to be Affected, pg. 8) in order to test the injectivity to water as part of a pilot project to determine the commercial viability of developing Qannik as an enhanced oil recovery project. The feasibility of water injection into the Qannik reservoir has not been established, and is therefore considered a "pilot" project. In May 2006, the CD2-404 exploration well was drilled to understand the ability to drill, complete, and produce the Qannik horizon. The well was drilled as an exploration well and tract operation within the CRU. No pool rules were in existence for this reservoir. The Qannik reservoir plan of development (POD) encompasses approximately 3200 acres of reservoir readily accessible from the Alpine CD2 drill pad. The current POD would ultimately have nine 6000-foot horizontal wells, six producers and three water injectors. The planned recovery scheme is a waterflood from the in-board injection wells with the addition of gas cap expansion drive to the eastern production wells. ConocoPhillips Alaska, Inc. (ConocoPhillips), as Operator and on behalf of the working interest owners, will apply to the AOGCC to establish pool rules and submit a complementary area injection order; and will apply separately to the State of Alaska, Department of Natural Resources (DNR) and Arctic Slope Regional Corporation (ASRC) to form a participating area, upon final determination of commerciality. Preliminary boundaries for the future participating area are shown on Figure 1 with the present CRU Boundary. Proposed development drilling is scheduled for May 2008, with field production commencement in late 2008. Page 3 ConocoPhillips Alaska, Inc. Application to the AOGCC for Âpproval of Pilot Water Injection into the Qannik Reservoir Colville River Unit '---" 20 AAC 25.402 (c)(1) Plat of Wells Penetratinq Iniection Zone The attached map (Figure 2) shows the existing CD2-404 well penetrating the injection zone in the proposed pilot injection area. The map also shows the areal extent of the Qannik POD, including all injectors and producers. Page 4 ConocoPhillips Alaska, Inc. Application to the AOGCC for ~roval of Pilot Water Injection into the Qannik Reservoir Colville River Unit ---- 20 AAC 25.402 (c)(2) Operators and Surface Owners within One Quarter Mile of I niection Operations Operator: ConocoPhillips Alaska, Inc. Attention: Matt Elmer P. O. Box 100360 Anchorage, AK 99510-0360 Surface Owners: Kuukpik Corporation Mr. Isaac Nukapigak PO Box 187 Nuiqsut, Alaska 99789-0187 Page 5 ConocoPhillips Alaska, Inc. - --- Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit 20 AAC 25.402 (c)(3) Affidavit of Tim W. Crumrine Reqardinq Notice to Surface Owners Tim W. Crumrine, on oath, deposes and says: 1. I am the Qannik Production Engineer for ConocoPhillips Alaska, Inc., the Operator of the Colville River Unit. 2. On September 21, 2006, I caused copies of the Application for Approval of Injectivity Test in the Qannik Reservoir Colville River Unit to be provided to the surface owner and operator of all land within a quarter mile of the proposed injection wells as listed below: a. Kuukpik Corporation Mr. Isaac Nukapigak PO Box 187 Nuiqsut, Alaska 99789-0187 3. On October 20, 2006, I caused copies of the Application for Approval of Injectivity Test in the Qannik Reservoir Colville River Unit to be provided to the surface owner and operator of all land within a quarter mile of the proposed injection wells as listed below: a. ConocoPhillips Alaska, Inc. Attention: Matt Elmer A TO-1750 P.O. Box 100360 Anchorage, Alaska 99510-0360 _'_ _ ij · ~~ ../ T· W. Crumrine STATE OF ALASKA ) ) SSe THIRD JUDICIAL DISTRICT) SUBSCRIBED AND SWORN to before me this 40th day of October, 2006. Î;., t.,. ~i'" ¡/'''''' f .---:. ..,....../" ·r.· . '" ," ,..d" \ ./ . JU', j':\....... \ ,¿j.1 ·nil ;' \ NO~y\·puÏ3ijc IN ÀND ~-ALASKA My Commission Expires: \ f..) .- . _!~ ~~ 'J Page 6 ConocoPhillips Alaska, Inc. Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit ~ 20 MC 25.402 (c)(4) Description of the Proposed Operation This application to the Alaska Oil and Gas Conservation Commission (AOGCC) seeks endorsement and authorization for the Qannik CD2-404 proposed pilot water injection project in the Colville River Unit (CRU), by asking for a variance to underground injection control and hence the Area Injection Order listed on the Permit to Drill (Number 206-054) under Article 20 MC 25.450 Section (a) as the injection will not occur into, through, or above freshwater as evidenced by conclusion (3) of Alpine Area Injection Order 18A; and Article 20 MC 25.450 Section (b) as a pilot project for enhanced oil recovery using a technology not proved feasible under the conditions in which it is being tested. This pilot project involves injecting 15,000 to 30,000 barrels of Beaufort seawater into the Qannik reservoir in order to test the injectivity to water as part of a project to determine the commercial viability of developing Qannik as an enhanced oil recovery project. The injected water will be flowed back to surface in a test to determine the level of downhole and/or surface sand control equipment needed upon injected water breakthrough. Determination of injection rate will depend on the outcome of a step rate test to determine fracture initiation pressure. Depending on the outcome of the pilot water injection and water injectivity test, the future Qannik development project includes ultimately drilling an additional eight wells from an extension of the Alpine CD2 drillsite. Current plans are for six wells are proposed to be producers and three wells (including the existing CD2-404 penetration) to be injectors. Unitized substances produced from the future Qannik Oil Pool will be commingled on the surface with substances from the existing Alpine Oil Pool. Similar to the existing allocation of unitized substances for the Alpine Oil Pool, production allocation for the future Qannik pool will be based on periodic well tests and producing conditions, e.g. up time; and injection allocation for the proposed pools will be based on meters on each injection well. Page 7 ConocoPhillips Alaska, Inc. Application to the AOGCC for ÀPproval of Pilot Water Injection into the Qannik Reservoir Colville River Unit "'-- 20 AAC 25.402 (c)(5) Description and Depth of Pool to be Affected The CD2-404 injection well is a tract operation within the CRU. A Qannik pool does not exist. Upon further determination whether commercially exploitable hydrocarbons exist within the Qannik reservoir, pool rules will be established and a participating area application will be submitted to DNR and ASRC. Until establishment of a Qannik pool, the Qannik reservoir is defined by the Alpine CD2-11 well with True Vertical Depth Sub Sea limits of 4,013 - 4,099 feet with a corresponding Measured Depth of 6,084 - 6,253 feet. Location of CD2-404 Well - based on NAD 27 Alaska State Plane 4 Surface X=371685 Y=5974497 Subsurface Well Heel (5,561 md) X= 369453 Y=5976684 Well Toe (11,540 md) X= 369023 Y= 5982642 Page 8 ConocoPhillips Alaska, Inc. Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit -- 20 AAC 25.402 (c)(6) Description of the Formation The Late Cretaceous Qannik sandstone represents a north-south elongate, eastward prograding shallow marine sand. The Nanushuk Group is broadly age equivalent to the Qannik. The Qannik sands in the CRU represent a Brookian topset play in which thin shallow marine sands (5-25 ft gross sand) are trapped stratigraphically and structurally. Over the CRU, the Qannik extends for at least 12 miles parallel to depositional strike (north-south) and six miles in a depositional dip direction. Updip, to the west, these sands pinchout due to either on lap or truncation beneath a ravinement surface. Its time equivalent shelf-slope break is roughly seven miles east of CD2 pad. The Qannik sandstone has been penetrated by over 120 wells in the CRU and over 60 wells in the vicinity of Alpine CD2 pad. Average core properties in the net sand are 23% porosity, 21 millidarcies air permeability, and 38% water saturation. The sands are lower very fine to lower fine- grained lithic arenites with average compositions of 30% quartz, 5% feldspar, 350/0 lithics, and 80/0 matrix. Sands with matrix content greater than 150/0 are generally non- pay. Illite, Smectite and other mixed layer clays are present in the core. The illite makes up approximately 11 % of the core and the Smectite and mixed layer clays make up roughly 80/0. The pilot water injection will answer questions regarding the performance of water injection. Water injection may activate clay swelling and there is a possibility of ion-exchange induced scale deposition. A downhole gauge will record pressure during a planned fall off test. The fall off test will aid in determining skin as a result of any clay swelling or scale deposition. Top Qannik structure elevation ranges from 3950 sstvd to 4029 sstvd over the Alpine CD1 and CD2 pads (Figure 1-1). Structural dips between closely spaced wells are generally less than 0.5 degrees. The Qannik accumulation is a combined structural- stratigraphic trap. A structural closure in the CD1 pad area, is interpreted to be gas filled above 4002' sstvd. Log analysis of approximately 50 wells with density and neutron logs shows consistent cross-over above 4002 feet sstvd. Page 9 ConocoPhillips Alaska, Inc. Application to the Aoacc for Approval of PH at Water Injection into the Qannik Reservoir Colville River Unit Figure 1-1: Qannik Top Structure Map MDT oil samples have been collected from 4027 sstvd in Nanuq 5 and from 4065 sstvd in Nanuk 2. In addition, the C02-11 core was fully oil saturated up to top Qannik at 4014 sstvd. Therefore, the hydrocarbon column is greater than 150-feet. 3D seismic indicates that there are no large faults in the development area. Sub- seismic faults may exist and would be associated with the younger north-south trending faults seen in the Alpine field. Confidence in picking sub-seismic fault trends is low due to static effects of overlying lakes and rivers. As no borehole breakout data is available at the Qannik level, a north northwest- south southeast maximum principle stress orientation similar to the Alpine field is assumed based on the orientation of the one seismically mappable fault. However, the presence of only one mappable fault suggests a potential decrease in overall stress compared with the Alpine level. Additionally, the level of induration of the Qannik interval points towards a low probability for the occurrence of interwell linking faults and fractures. Thus, the overlying concern for well orientation is alignment with the trend of the gas-oil contact (approximately 5 degrees west of north). The oil accumulation around C02 pad is clipped to the east by the GOC, and by stratigraphic pinchout of reservoir sands to the north and west. To the south, oil bearing sand continues south of C04 pad. Net pay averages about 15-feet thick over the C02 pad area. Porosity varies from 20- 26%, and permeability varies from 10 - 50 MD. Grain size is considered very fine. Page 10 ConocoPhillips Alaska, Inc. Application to the AOGCC for laval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . Geochemical analyses have been completed on oil extracted from the CD2-11 core and from MDT oil samples in Nanuk 2 and Nanuq 5. The black oil extracts are interpreted to be sourced from the calcareous facies of the Shublik and the light hydrocarbon components to come from Jurassic shales. API gravity is 27-31 degrees. Additional geological and geophysical work and studies are planned to be conducted. From the geophysical perspective, both fluid and rock property effects on the Qannik seismic response will be examined. A static geological model (geocellular model) will be constructed incorporating updated structural mapping, the revised log model, and the drilling and test results from the CD2-404 well. This geocellular model will provide the framework and property distributions for a new simulation model that will be used in updating and refining volumetrics and reserves distribution. The areal extent of the Qannik reservoir from the CD-3 pad is approximately 3 miles west, 1.5 miles east, and 3 miles south with the gas cap bounding the northern extent % mile from the pad. The areal extent of the Qannik reservoir from the CD-4 pad is approximately 2 miles west, and 1.5 miles north with a pinch-out bounding the southern and eastern extent % mile from the pad. Pressure-Volume-Temperature test results for the Nanuq 5 MDT sample are summarized in Table 1. The Nanuq 5 well falls outside of the current Qannik POD area, but can provide insight into the expected reservoir properties until further laboratory analysis on downhole samples collected from the CD2-404 well is conducted. Gas-oil ratio, relative oil volume, and API gravity data are reported for differential vaporization tests. Nanu 5 Qannik 8.9 420 1.2 29 Rock Mechanics From core studies, the Qannik horizon appeared to have relatively low rock strength and had a high potential for borehole collapse and associated sand production. Sand strengths tested via Dimpler were 996-2580 psi unconfined compressive strength (UCS) and mudstone strengths tested with the Dimpler were 160-883 psi UCS. Core samples showed a high degree of softness, gumminess, and plasticification of the mudstones giving a feel of weakening-softening. Dipole sonic data from offset wells consistently show higher UCS values. Weakening of core could have been caused by WBM coring fluid in CD 2-11 reacting with the swelling clays. With this understanding, the completion method called for running slotted liner with blank and swelling elements to reduce sand/silt influx into the wellbore. The blank pipe and swelling elements were Page 11 ConocoPhillips Alaska, Inc. Application to the AOGCC for laval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . placed across intervals with higher probability of sanding determined by both well logs and core samples. Sand production was negligible during the flowback with only trace amounts of solids returned. Page 12 ConocoPhillips Alaska, Inc. Application to the AOGCC for .oval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 AAC 25.402 (c)(7) L02S of the Iniection Wells CD2-404 well logs have been sent to the Commission by Halliburton - Sperry Sun, on behalf ConocoPhillips Alaska Incorporated. Page 13 ConocoPhillips Alaska, Inc. Application to the AOGCC for 'oval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(8) Casino Description and Proposed Method for Testino The proposed underground injection into the Qannik reservoir (undefined pool) will occur through the CD2-404 injection well permitted as an exploratory/injection well in conformance with 20 MC 25.005. A CD2-404 well schematic is included as Figure 4. Casinq Description For proper anchorage and to divert an uncontrolled flow, 16-inch insulated conductor casing was drilled and cemented to 114 feet below pad. Cement returns to surface were verified by visual inspection. Primary, secondary, and general well control for drilling and completion operations were performed in accordance with 20 MC 25 Articles 01 and 06. Casing and cementing were performed in accordance with 20 MC 25.030. Surface casing was set at 2378 feet true vertical depth and cemented to surface. The intermediate hole was drilled to the target zone and production casing was cemented with the shoe in the target zone. Leakoff / formation integrity tests were successfully performed on the surface casing shoe and the production casing shoe. The production casing was cemented to 3766 feet true vertical depth. The injection hole was drilled beyond the casing shoe horizontally in the target zone. The CD2-404 well was completed using slotted liners with blank pipe sections and constricting packers within the injection hole. Tubing and packer were run to isolate pressure to the injection interval consistent with 20 MC 25.412. Proposed Method for Testinq Casing-tubing annulus pressures will be monitored and reported during injection operations in accordance with 20 MC 25.402( e). Automated monitoring of injection rates, tubing and casing-tubing annulus pressures is planned. Prior to commencement of injection, the CD2-404 injection well will be pressure tested in accordance with 20 MC 25.412(c). In the event pressure observations or tests indicate communication or leakage of any tubing, casing, or packer, ConocoPhillips will notify the AOGCC within 24 hours of the observation to obtain AOGCC approval of appropriate corrective actions. AOGCC approval will be received prior to commencement of corrective actions unless the situation represents a threat to life or property. Page 14 ConocoPhillips Alaska, Inc. Application to the AOGCC for laval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(9) Injection Fluid Analvsis and Injection Rates The water injection plan for the Qannik reservoir (undefined pool) is based supplying Beaufort seawater to C02-404 using a water pipeline between the Alpine Central Facility (ACF) and Drill Site C02. Compatibility of the Beaufort seawater and the Qannik reservoir is unknown and is a major factor for conducting this pilot water injection. Injection rates will be managed based on a step rate test conducted during the pilot water injection. Total injected volume of water is expected not to exceed a proposed 30,000 barrels of water. The proposed injection volume of 15,000 to 30,000 barrels of water is based on the volume of water needed to fill one reservoir pore volume 10 - 15 feet radially from the wellbore assuming 2/3 of the wellbore is producing as indicated from logging. Injection rates are expected to average 1,500 to 3,200 barrels of water per day. Page 15 ConocoPhillips Alaska, Inc. Application to the AOGCC for 'oval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(10) Estimated Pressures As part of this pilot injection, wellhead pressures will be monitored in order to keep water injection at rates in which the rock matrix will accept fluid without exceeding the tensile strength of the rock thereby initiating and propagating a hydraulic fracture. However, it may be necessary to temporarily inject above parting pressures to determine if voidage replacement volumes can be injected. Relative permeability to water tests have not been conducted and offset or analogous Qannik wells do not exist to calibrate pressure modeling. The current estimate of wellhead pressure at during injection is 1,300 psi to 2,400 psi, but this is subject to change as more information is gathered. Page 16 ConocoPhillips Alaska, Inc. Application to the AOGCC for .oval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(11) Fracture Information Information on fracture initiation and propagation for the Qannik interval does not exist. During the proposed pilot water injection both surface and downhole gauge data from a step rate test will be recorded to determine fracture initiation, propagation, and leak-off properties of the injectant. Page 17 ConocoPhillips Alaska, Inc. Application to the AOGCC for .laval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(12) Quality of Formation Water Formation water has not been produced in significant quantities from CD2-404. A Karl Fischer titration was conducted on a surface sample collected from the well and showed a water cut of 0.5% v/v. Bottom-hole samples have been collected and are currently undergoing analysis to determine quality. In the Qannik reservoir no water-oil contacts have been observed. A salinity was calculated for the CD2-404 well in the proposed pilot injection area. Rw was obtained using the same connate water salinity as was used for the Alpine and Fiord reservoirs, equivalent to 0.27 ohm-m at 68 deg F. For reservoir temperature of 94 deg F (using the Alpine temperature gradient), Rw = 0.20 ohm-m. This represents a salinity of about 28,000 parts per million. Page 18 ConocoPhillips Alaska, Inc. Application to the AOGCC for .val of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 AAC 25.402 (c)(13) Aquifer Exemption Reference No underground sources of drinking water exist beneath the permafrost in the CRU area. See Area Injection Order 188 (October 7,2004) conclusion 3. The proposed Qannik pilot water injection has an affected area entirely within the CRU area. Page 19 ConocoPhillips Alaska, Inc. . Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 MC 25.402 (c)(14) Incremental Hydrocarbon Recovery There is no incremental hydrocarbon recovery associated with this Qannik pilot injection project. No offtake wells currently exist within the reservoir. Reservoir modeling indicates minimal changes in water saturation away from the well bore. Example water saturations can be found in Table 2. Table 2 - Water Saturation Changes Delta Water Distance from Saturation Well bore (Feet) 0.04 130 0.10 70 0.15 20 A graph of well bore and near wellbore (approximately 5 feet away) pressures can be found as an attachment. Page 20 ConocoPhillips Alaska, Inc. Application to the AOGCC fo!proval of Pilot Water Injection into the Qannik Reservoir Colville River Unit . 20 AAC 25.402 (c)(15) Mechanical Condition of Wells Within ~ Mile of Proposed Area All wells drilled within a X mile radius of the Qannik CD2-404 pilot injection interval were drilled in accordance with 20 MC 25 Articles 01 and 06. Completion reports of these wells are submitted as attachments. Each of the wells intersecting a X mile radius of the CD2-404 wellbore is not cemented across the Qannik injection interval. Based on expected pressure increases in the Qannik reservoir resulting from the pilot injection, casing collapse pressures are not exceeded. Wellbore and near wellbore reservoir pressure modeling for a 10 day, 30,000 Barrel water injection (see attachments) shows a maximum wellbore injection pressure of 3,800 psi. The collapse pressure for the existing Alpine 7" 26 ppf L-80 casing is 5,410 psi. In addition, there are no significant hydrocarbon bearing zones, or freshwater zones near the Qannik reservoir to accept injected water via fracturing or annular bypass of nearby wells. As evidence that there are no freshwater zones please refer to conclusion (3) of Alpine Area Injection Order 18A. The proposed Qannik development overlies the Alpine reservoir with an areal extent contained within the CRU; injection therefore should not contaminate any freshwater sources. The Bergschrund 1 log (see attachments) shows no significant hydrocarbon bearing zones above the Qannik (K2) formation at least until the required casing points in the Alpine - Qannik penetrations. This distance is approximately 1600 ft TVD. Sands above the Qannik (K2) interval show minimal thickness, very little resistivity contrast and contain a considerable amount of interbedded shales. Below the Qannik reservoir the next hydrocarbon bearing zone is the Alpine C sand, which is cemented and separated by approximately 2,800 - 3000 feet of shale. The sands below the Qannik also show little resistivity contrast and are considered wet. In addition these sands are low porosity when compared to the Alpine sands below. Evidence of their low porosity can be seen as their densities approach 2.65 g/cc. Page 21 ConocoPhillips Alaska, Inc. Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit Figure 1 Proposed Affected Area for Qannik Page 22 ConocoPhillíps Alaska, Inc. Application to the AOGCC for Approval of Pilot Water Injection into the Qannik Reservoir Colville River Unit 5!1ßl ~c'c ,~ soo"c 5¥:'1Ioo{; " 5\)'!S¿¡lh 597'7000 5\)~1i'3 Ei'Œ.'tmg r¡¡Ct110ftimj 370(;'*::1'0 Figure 2 % Mile CirclefTangent with Existing CD2-404 Well and Alpine - Qannik Penetrations. The two wells marked in green are outboard producers and the well marked in blue is the CD2- 404 well. Page 23 ConocoPhillips Alaska, Inc. Application to the AOGCC fo pproval of Pilot Water Injection into the Qannik Reservoir Colville River Unit Figure 3 Proposed Qannik Field Development :4 Mile Circle Tangent around proposed Qannik Injectors. Wells marked in marked in green are outboard producers and the wells marked in blue are the inboard injectors. The CD2-404 is the northernmost well marked in blue. Page 24 ConocoPhillips Alaska, Inc. Application to the AOGCC for Approval of Pilot Water If0ection into the Qannik Reservoir Colville River Unit CD2-404 Kanik injector Completion 16" Insulated Conductor to -114' 3-%" x 4-%" cross-over. 2 jts below 4-%" hanger 3-%" 9.3 ppf L-80 EUE 8rd Mod Tubing 2.813" TRMAXX SCSSSV 10-%" 45.5 ppf L-80 MBTC Surface Casing 2693' MD 12378' TVD 7 UplJer Completion: Top MD TVD It!ml 1) Tubing Hanger 32' 32' 2) 4-%" 12.6 #/ft IBT-Mod Tubing (2 jts and pups) 3) Crossover 4) 3-W', 9. 3#/ft , EUE 8rd Mod Tubing 5) Cameo TRMAXX SCSSSV 2237' 2008' 6) 3-%", 9.3#lft, EUE 8rd Mod Tubing 7) Cameo KBMG- GLM (2.867" 10) 4506' 3765' 8) 3-W', 93#1ft, EUE 8rd Mod Tubing 9) Cameo KBMG- GLM (2.867" 10) wi OCK-2 shear valve installed (3000 psi) 4626' 3828' 10) 3-W', 9.3#111. EUE 8rd Mod Tubing (2) 11) HES "XN" (2.750")- 63.0' inc 4705' 3865 12) 3-W', 9.3#Ift, EUE 8rd Mod Tubing 2jts 13) BOT bonded seal assembly wlhalf mule shoe 5359' 4058' Stung into seal bore an tieback extension 10', bottom at 5369' Lower Completion: It!ml 14) Baker ZXP Liner top packer 15) Baker RS Nipple 16) Baker 5" x 7" Flexlock Liner Hanger 11) Seal bore extension 18) 3-%",9.3#111, SLHT Tubing +1- 23 jts 19) 3-W' 9.3#1ft L-80 SLHT liner wi blanks and constrictors across shale and slots across sand 20) Baker Shoe wi packoff bushing Too MD TVD 5331' 5350' 5353' 5363' 4054' 4051' 4051' 4058' 11083' 4075' Top Reservoir at +/- Kanik 5496' MD I 4072' TVD 7-5/8" 29.7 ppf L-80 BTC Mod Production Casing @ +/-90° 5561' MD, 4077' TVD TO 6-3/4" hole 11540' MD 14071' TVD Updated by J. Haas 6/1/06 Figure 4 CD2-404 Injector Well Schematic Page 25 ConocoPhillips Alaska, Inc. . . Application Attachments Qannik Pilot Injection Attachments to Application to the AOGCC for Approval of Pilot Water Injection in the Qannik Formation Colville River Unit ConocoPhillips Alaska, Inc Anadarko Petroleum Corporation October 20,2006 Application Attachment Qannik Pilot Injection Wellbore and Near Weilbore Reservoir Pressure Modeling for 10 day - 30000 Barrel Qannik Pilot Water Injection 4500 4000 í? ïii 3500 ß Q) 3000 ... ::¡ tf¡ tf¡ Q) 2500 ... Q. "C .;: CI 2000 ëi3 š: 1500 . 1500BHP ... 1500WellGridP 0 Q. 2000BHP :;¡: 1000 00 2000WellGridP 500 % 3000BHP * 3000WellGridP Pressure Profile for Injectivity Test o o 2 4 12 18 20 14 16 6 8 10 Time (Days) ConocoPhillips Alaska, Inc. .. . ...... .... ~ Sand, unconsolldllted, ~';;;' pebble/gravel fragments ~.i: As ebove with woody .-=::~ debrfslcoa fragments ~ -'-l~ Clay ~::- :~'ì, SIltstone, Coellnterbeds Shale 9 518" SURFACE CASING Sandstone --- Shale :::::. Sntstone Siltstone Sandstone/siltstone ~' I ~=i _._.:c §2 i! ~{=~ Sandstonelslltstone Shale Sandstone/siltstone BIT TRIP FOR BUILD ASSEMBLY Claystone 7"INTERMEDIATE CASING Sandstftne ....:.... Siltstone ~ EË ª-~ ~$- ~ Claystone Sandstone . .... '"III BERGSCHRUND_1 .....- .... - t :IE e~ -'::>:>,-~- t - '. -, - - - - _ ~ S300 ~~~ ~J --~~:~:;,~, .... _ ..;I.,M -~~Z~~'~:'?~ 640D -- .!i.. .... ~ -~;. .... - .~~ .788 -:;:~~,.+-~ Be" ..:.."" ?-:;-: -~~~ ow;;.:: ~~~,. ) ~~~~..:;~ SStvD .. "K! 2QO ... ... ,.. ... '00 ... ... _.. .. . .. . ~, .... . 10PS TO!' UGIR/ ..,. . ": ~~ ~ ...iii!fiE" - -- --s..-=- :=;,._"_ -..!!!!!!!!!!!i!!! .......=-..- ..- ~~ T":'::: > C_::: -;,. 1=- Shale, Volcanic ash "<.;. S ._~~ .::.. 1800 ~~._~. .. " .. a-:- --~:~"- 2100 ~,... .~~.;::- 23DO Sandstone . '. .. --~..... ,.... SlIIstons . -. . --~~_ .... ..:~:~M : ~.~ _~...~::.... 2800 Jt=tr- 2900 . .",,- Shale I-~~ .~ :: E-:"'-:= ~ ~ ~ ~ ;E: -- ~~ Siltstone ~ .=: - Sandstone ~ -.. '. ..,...... ~ :.-r -- ~.::~ '-. "'00 ~(J: ~ -( -4 ...~' 4100 .-fr -\. _-{ ".,.) 4700 5t l~ .t8QO ~ --~:_ 49111J ~:~i-1 - ~ -j,. !ltOO _~. }: 5200 ~ -~ .' 111R! . -;"~ --- .. .,=,,- ,... ;,-~.;-. .-..-"- .. ,- 'AIR! ,... .. '000 ''''' '98' .~~~ -:'i~= '.c -'~~'- .:::..~;...-- .... ...f~;--:· "f .1": -~fj-:'" ,p'" .~~.- ,... ,'. ;~- - t. :¡.:. , .I- i::: -.. ~ ~:1;:- ":'-)0- ~;: 3400 3500 3000 3"" -....". 3800 ..-;j:- P",:,,:..:-. .- f .: .... ',' -'n"" ~. t t ~ i- ~ I L- , j -1 ~--- ..); -~f -,-> ~f'- -~'. -; 54... ~~~,... , =.~ _1" 1'.;' 58.. .... 070. .... J-r-'- -0/ :L ( ,j .... .... "GO .... .' :\P-- r~~:;~J _ .~¿. .-'.,... ~'.- :1.. ,,;,- ",.- 1000 "00 '. ~~/¡;- ~- ,... ..--.j; 7400 . ......,¡ ~.. ;~.:- - - - '"""" ~ ~ ...:; ~ 10P W.IAK ~ BASEW.SAK -- -=' ALII'" . HRZ I; I 1 AOP.we_ 3tI mtA ROP MAX-eo FTIHR ... ......... FM. IIOP AVI- JØ t"I7HfI: AVE GAS- as UNJTS LCU - ~ FM. MAX GAI_ UNmI ........ ROP MAX .~11 mHIt 1N1000-UOUHrra ......... - i ! I I !'I IÆCIÆUK ~ t::.- ~ ~ - ..~'- ,:". -"""'.'. .- -- "pl. ~':... .f:,;- ~ , ~~t Jsf "5~:~-- "~"'~~ "'io:- ~-' ~~ - iJ· ~ -f~ .\}. ~.c,,- .]: ~J =< ¡ ~~¥::~i:- .~ ~F ..¡ .'. ...... .?t ~~.~ -~:~~~$ ~~':¡;:~ -~- --.- ~ ......~-:; ", ::- ...;;!- ~.~ , ..'[~- '¡ '-, 'e . ;N ..~~~_ I ROP MAX -HI","" HOP Ave -10 FTlHR .... 21 ¡ I c·,. ~ I i i 5! ~ i II i i ~ u.. !'I HOP AVE -1" FTIHR I I .:j ~ -- = ~ c..MI(Ko1111 -= C0381K-11 .- .. ............ .......C ...... D " ;< i ; .... " b ~9 '" AGE Rap (COI42 _I GAS I RaP AW_1II FTIHR I 5! I § B I m ~ I AYlIMB - H Utm'8 flOP MAX-US FTftIR MAXOAS - 1211 urma II1RONG HOI.EWABHOUT II! I ~ë 0AS1IICft!AII! BILDW_ CSGAlAPP!ARS RaP AVI! _1.. PTlHR I MOD HOI.8 WAlMOUT AVE GAS -100 UNn'I MAX 1IAS_14II UHmI ROP MAX. 1on","1t ROPAYS·2HFTIHR. AVI GAS _. UNfT8 HOP Aw-n FrIHR I ROPAve-IDFmIR AW. GAB -10 UNITS ROIl Ave_ 1DD nItIR ROPMAX - 210 nAtR MAX GAS -21.UNmI ~ i I AVI!OAS-:SOUNn'8 ROP Ave - II PTlHR CI aM API'IARS as GAS APPEARS AVE GAS -11S UNmt MAXGAS350UNn'S AVEGM -31 UMnS AVEGAS_IctUNn'!I AYI GAS- MOUNIT.8 nap MAX-I4OFTIHR " MAX GA8150 UNrrs AvaGAS _ U UNITS i i i ROP Ave-,. FTlHR MAX GAS 12SUNmI I I ROPMAX-naFffHR Ave GAIa TO UNn I I AVEOAI-aoUIfITS MAX OM 210 UHmI ROP AVE _121 FrIHR RaP MAX - M FmtR AVf. GAS- TO UNITS . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil 0 GasU Plugged 0 Abandoned 0 Suspended 0 WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WlNJ 0 WDSPL 0 No. of Completions Other . Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 30, 2005 205-092 I 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 July 11, 2005 50-103-20512-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: i Surface: 1597' FNL, 1560' FEL, Sec.2, T11N, R4E, UM July 25, 2005 CD2-03 At Top Productive 8. KB Elevation (ft): 15. FieldlPooI(s): I Horizon: 2079' FNL, 1000' FEL, Sec. 27, T12N, R4E, UM 36.7' RKB, 52~AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): Alpine Oil Pool 357' FNL, 1965' FEL, Sec. 27, T12N, R4E, UM 15682' MD I 7132' ìVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 371685 y- 5974761 Zone- 4 15682' MD 17132' ìVD ADL 25529, 387211, 25530, 380075, 387211 TPI: x- 367128 y- 5984919 Zone- 4 11. Depth where SSSV set 17. Land Use Permit Total Depth: x- 366191 y- 5986658 Zone- 4 2322' ALK ASRC NPRA02 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1747' MD 21. Logs Run: GRlRes, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE wr. PER FT. CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 114' Surf. 114' 42" Portland Cement 9-518" 36# J-55 Surf. 3260' Surf. 2381' 12.25" 519 sx AS Lite, 230 sx Class G 7" 26# L-80 Surf. 13774' Surf. 7111' 8.75" 30 bbls Mudpush XL, 191 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number, if none, state "none'1: SIZE DEPTH SET (MD) PACKER SET 4.5" I 3.5" 121'/13130' 13072' open hole completion from 13774'-15682' MD, 7111'-7132' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTHINTERVAL~D) AMOUNT AND KIND OF MATERIAL USED 26. . PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVI1Y - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD 1VD Include and brieflY summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-03 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TD 3334' 6448' 12800' 13299' 13465' 13643' 13661' 13699' 15492' 15682' 2416' 3864' 6795' 6994' 7039' 7086' 7090' 7098' 7117' 7132' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 p~nted Nam~./ ~ord Signature L' / .' Title: Phone Alpine Drillina Team Leader '2.46"' -(; IU Date Ii II e-l ~ Þ~')" Prepared by Sharon AlIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . . 1a. Well Status: Oil [2] Gas U Plugged U Abandoned [J Suspended 0 WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: September 12, 2004 204-129/ 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 August 22, 2004 50-103-20496-00 / 50-103-20496-70 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1656' FNL, 1552' FEL, Sec. 2, T11N, R4E, UM September 7,2004 CD2-09 / CD2-09PB1 At Top Productive 8. KB Elevation (It): 15. ReldlPool(s): Horizon: 351' FSL, 2412' FWL, Sec. 27, T12N, R4E, UM 36.7' RKB / 52.6' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): Alpine Oil Pool 1556' FNL, 553' FWL, Sec. 27, T12N, R4E, UM 16409' MD / 7169' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 371690 y- 5974702 Zone- 4 16409' MD 17169' TVD ALK 380075, 387212 TPI: x- 365214 y- 5982103 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 363410 y- 5985509 Zone-4 SSSV @ 2282' ADL nla 18. Directional Survey: Yes [2] NoU 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 1795' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE GRADE CEMENTING RECORD PULLED WT. PER FT. TOP BOTTOM TOP BOTTOM SIZE 16" 62.5# H-40 Surface 114' Surface 114' 42" 13 cu yds Portland III 9.625· 36# J-55 Surface 3385' Surface 2380' 12.25" 501 sx AS Lite, 241 sx Class G 7· 26# L-80 Surface 12617' Surface 7172' 8.5" 167 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none'): SIZE DEPTH SET (MD) PACKER SET 3.5· 12102' 12035' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. open hole completion from 12617'-16409' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) October 12, 2004 Gas Lift Oil - Production shared with CD2-09L 1 Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 10/13/2004 5-3/4 hours Test Period -> 688 631 0 82% 816 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. 259 ps 1064 24-Hour Rate -> 2540 2072 0 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state 'none". NONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Revised 12/2003 CONTINUED ON REVERSE . . 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-09 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TD 3446' 5902' 11696' 12123' 12229' 12370' 12478' 12557' 16340' 16409' 2412' 3851' 6821' 7034' 7076' 7125' 7152' 7164' 7219' 7169' N/A CD2-09PB1 TD 13926' 7161' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 p~nted Na~.. {tt0rd Signature _ L Title; Phone Alpine Drillina Team Leader ~-(, no Date loJ~"f- Sharon Allsup-Drake @ 263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Altemating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well Is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate ·none'. Item 29: List all test information. If none, state ·None·. Form 10-407 Revised 12/2003 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil D Gas U Plugged D Abandoned D Suspended D WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development D Exploratory D GINJ D WlNJ D WDSPL D No. of Completions _ Other - Service 0 Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number. ConocoPhillips Alaska, Inc. or Aband.: October 8, 2005 205-1321 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510-0360 September 16, 2005 5()"'103-20515-00 4a. Location of Well (Govemmental Section): 7. Date TO Reached: 14. Well Name and Number. Surface: 1676' FNL, 1550' FEL, Sec. 2, T11 N, R04E, UM October 6, 2005 CD2-11 At Top Productive 8. KB Elevation (ft): 15. FieldlPool(s): Horizon: 83' FSL, 842' FWL, Sec. 34, T12N, R04E, UM 36.1' RKB Colville River Field Total Depth: 9. Plug Back Depth (MD + NO): Alpine Oil Pool 1243' FNL, 1262' FEL, Sec. 28, T12N, R4E, UM 18187' MD 17197' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + lVD): 16. Property Designation: Surface: x- 371692 y- 5974682 Zone- 4 18187' MD 17197' TVD ADL 380075,387212, ASRC NPRA-1 TPI: x- 363640 y- 5981863 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 361601 y- 5985856 Zone- 4 nipple @ 2286' ALK ASRC NPRA02 18. Directional Survey: Yes 0 NoD 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1695' MD 21. Logs Run: GRlRes 22. CASING, LINER AND CEMENTING RECORD SETIING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 37' 114' 37' 114' 42" Portland Cement 9-5/8" 40# L-80 37' 2825' 37' 2383' 12.25" 410 sx ASUte, 230 sx Class G 7" 26# L-80 37' 13809' 37' 7213- 8.5" 210 sx Class G 23. Perforations open to Production (MD + NO of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 12734' 12660' open hole completion from 13809' to 18187' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 26. PRODUCTION TEST Date First Injection Method of Operation (Flowing, gas lift, etc.) not available Injector Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) press. psi 24-Hour Rate -> I 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". REFER TO ATTACHMENT Form 10-407 Revised 12/2003 CONTINUED ON REVERSE . . 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted. state "None". CD2-11 Seabee Formation 2883' 2406' Nanushak 5637' 3845' Gamma Ray Shale 12424' 6852' Kalubik 12955' 7066' Kuparuk Formation 13112' 7109' Miluveach 13361' 7161' Top Alpine D 13610' 7196' Top Alpine C 13699' 7206' Base Alpine C 18120' 7199' NIA TD 18186' 7197' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT, core summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vem Johnson @ 265-6081 Printed Na~ Chip Alvord Title: Alpine Drillina Team Leader .1-( 1...î. { ()"') Signature 'L tk.t Phone z..ú"r - CI t 2-ø Date Prepared by Sharon Allsu¡rDrake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. . Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, other (explain). Item 27: If no cores taken, indicate "none", Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended U WAGE! 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service E! Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., t2. Permit to Drill Number. ConocoPhillips Alaska, Inc. or Aband.: May 19, 2003 203-073 I 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510-0360 May 4, 2003 50-103-20455-00 4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number. Surface: 1686' FNL, 1549' FEL, Sec. 2, T11 N, R4E, UM May 17, 2003 CD2-12 At Top Productive 8. KB Elevation (It): 15. FieldlPool(s): Horizon: 1860' FSL, 886' FWL, Sec. 35, T12N, R4E, UM 36.6' RKB I 52.5' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + TVD): Alpine Oil Pool 985' FSL, 1457' FEL, Sec. 27, T12N, R4E, UM 13632' MD I 7117' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 371693 y- 5974672 Zone- 4 13632' MD I 7117' TVD ADL 380075,387212,25530 TPI: x- 368906 y- 5978266 Zone-4 1 t. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 366636 y- 5982712 Zone- 4 Land Nipple @ 2195' N/A 18. Directional Survey: Yes E! NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1700' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42· Pre-installed 9.625" 36# J-55 Surface 2657' 12.25" 434 sx AS III Lite, 230 sx ArcticSet 7" 26# L-80 Surface 8677' 8.5" 155 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4.5· 8365' 8270' open hole completion from 8677' to 13632' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE Submit in duplicate · , . , 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state 'None'. CD2-12 Seabee Form. 2680' 2401' Nanushak 4432' 3847' Gamma Ray Shale 8054' 6810' Kalubik 8307' 6984' Kuparuk Formation 8387' 7030' Miluveach 8524' 7093' Top Alpine D 8580' 7112' Top Alpine C 8635' 7126' Alpine A 8769' 7144' NIA Base Alpine C 13620' 7118' Base Alpine inverted 13401' 7145' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vem Johnson 265-6081 Printed Name 13., ç. Alvord Signature~- t. ~ Title: Phone Alpine Drillina Team leader Date 7{fS(O) Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Altemating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate 'none'. Item 29: List all test information. If none, state 'None·. Form 10-407 Revised 2/2003 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . . . , . 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 8] WAG Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-159 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20386-00 4. location of well at surface 9. Unit or lease Name 1716' FNl, 1545' FEl, Sec. 2, T11 N, R4E, UM (ASP: 371696,5974642) Colville River Unit At Top Producing Interval 10. Well Number 401' FSl, 1731' FEl, Sec. 34, T12N, R4E, UM (ASP: 366266, 5976854) CD2-15/ CD2-15PB1 & CD2-15PB2 At Total Depth 11. Field and Pool 890' FNl, 1375' FWl, Sec. 34, T12N, R4E, UM (ASP: 3641S7,S980881) Colville River Field 5. Elevation in feet (indicate KB, DF. etc.) 6. Lease Designation and Serial No. Alpine Oil Pool RKB 37' feet ADl 380075 /387212 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions October 5, 2001 October 28, 2001 October 30, 2001 NIA feel MSl 1 17~ Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 14161' MD 17228' TVD 14161' MD 17228' TVD YES 8] No 0 NIA feel MD 1568' MD 22. Type Electric or OIherLogs Run GRlRes 23. CASING, UNER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PEl'! FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PUlleD 16· 62.5# H-40 Surface 114' 42· 300 sx AS 1 9.625" 36# J-SS Surface 2656' 12.25· 399 sx AS III Ute, 240 sx Class G 7" 26# l-80 Surface 9829' 8.5" 132 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 9307' 91:97' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A NIA 27. PRODUCTION TEST Date Rrst Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for Oll-BBl GAS-MCF WATER-BBL CHOKE SIZE GAS-Dll RATIO Test Period > Flow Tubing Casing Pressure Calculated OIL -BBL GAS-MCF WATER-BBl Oil GRAVITY - API (corr) press. psi 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil. gas or water. Submit core chips. -N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ( \ .. 29. 30. GEOLOGIC MARKEF..... FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-15 Top Alpine D Top Alpine C Base Alpine 9554' 9605' 9700' 7173' 7189' 7212' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vem Johnson 265-6081 Signed /~ t..M_ Chip Alvord Tille Alcina Drillina Team leader Date -4lJŠ (:/2__ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correèt well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Itém 23: Attached supplemental records for this well should show the details of any multiple stage cementing and thé location of the cementing tool. Item 27: Method of Operation: Rowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fonn 10-407 ( ) .) . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil 0 Gas U Plugged 0 Abandoned U Suspended U WAG 0 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WlNJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic TesD 2. Operator Name: 5. Date Comp., Susp., 12. Permitto Drill Number: ConocoPhillips Alaska, Inc. or Aband.: February 7, 2005 204-245 I 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 December 28, 2004 50-103-20504-00 4a. Location of Well (Govemmental Section): 7. Date TO Reached: 14. Well Name and Number: Surface: 1775' FNL, 1538' FEL, Sec. 2, T11N, R4E, UM February 3, 2005 CD2-21 / CD2-21 PB1 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 1638'FNL,69'~,Sec.34,T12N,R4E,UM 36.9' RKB /52.8' AMSL Colville River Field Total Depth: 9. Plug Back Depth (MD + lVD): Alpine Oil Pool 1580' FNL, 2801' FEL, Sec. 28, T12N, R4E, UM 19359' MD /7175' lVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + lVD): 16. Property Designation: Surface: x- 371703 y- 5974582 Zone- 4 19359' MD /7175' lVD ADL 380075,387212 TPI: x- 362840 y,.. 5980157 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x-360057 y- 5985547 Zone- 4 SSSV @ 2314' ALK ASRCNPRA 02 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1690' MD 21. Logs Run: GRlRes, DenslNeutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE CEMENTING RECORD TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36.9' 114' 36.9' 114' 42" Pre-Set 9.625" 36# J-55 36.9' 3085' 36.9' 2364' 12.25" 434 sx AS Lite, 239 sx Class G 7" 26# L-80 36.9' 13382' 36.9' 7216' 8.5" 215 sx Class G Abandonment plug # 1 @ 20095' - 19341' abandonment plug #2 @ 18851' to 17722' abandonment plug #3 @ 8712' to 8108' 23. Perforations open to Production (MD + lVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none'1: SIZE DEPTH SET (MD) I PACKER SET 4.5" 13.5" 124' /12560' I 12501' open hole completion 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Plug #1 from 20095' to 19341' 63 bbls 15.8 ppg Class G Plug #2 from 18851' to 17722' 48 bbls 15.8 ppg Class G Plug #3 from 8712' to 8108' 53 bbls 17 ppg Class G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 12, 2005 Gas Lift Oil Date otTest Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS.OIL RATIO 5/12/2005 5 hours Test Period -> 631 327 0 53% 741 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 876 psi 726 24-Hour Rate -> 2700 2001 0 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ,1' (. J .. . . 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. Ust intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-21 Seabee Form. nla Nanushak 6021' 3836' Gamma Ray Shale 10261' 5903' Kalubik 12645' 7069' Kuparuk Formation 12646' 7069' Miluveach 12980' 7161' Top Alpine D 13164' 7198' Top Alpine C 13290' 7211' Base Alpine C 19245' 7183' NIA TD 19359' 7175' CD2-21PB1 TD 20171' 7786' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vem Johnson @265-6081 Printed Name C. Alvord TItle: Alpine Drillina Team Leader Signature~ ~ (kA. Phone 2.(,. ç - Go l 2....0 Date S-((~ (O~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interva~. Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ,> , ... . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 202-1341 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20425-00 / 50-103-20425-70 4. Location of well at surface 9. Unit or Lease Name 1795' FNL, 1536' FEL, Sec. 2, T11N, R4E, UM (ASP: 371705, 5974562) Colville River Unit AtTop Producing Interval 10. Well Number 1789' FSL, 772' FEL, Sec. 34, T12N, R4E, UM (ASP: 367248, 5978224) CD2-23 I CD2-23PB1 At Total Depth 11. Field and Pool 49' FNL, 2631' FEL, Sec. 34, T12N, R4E, UM (ASP: 365445, 5981699) Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Alpine Oil Pool RKB 37' leet ADL 380075,387207,387212 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Compfetions July 1, 2002 July 21, 2002 July 24, 2002 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permalrost 13438' MD 17181' TVD 13438' MD 17181' TVD YES 0 No 0 SSSV @ 2099' MD 1689' MD 22. Type Electric or Other Logs Run GR/Res/NeuVDens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16· 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 1/1 9.625" 36# J-55 Surface 2627' 12.25" 348 sx AS III Lite, 233 sx Class G 7" 26# L-80 Surface 9676' 8S 130 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intérval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9288' 9190' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Rowing, gas lilt, etc.) August 6, 2002 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-DIL RATIO 8/21/2002 12 hours Test Period> 1638 1561 0 99% 953 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 232 psi 1451 24-Hour Rate> 3276 3121 0 not available 28. CORE DATA Briel description of lithology, porosity, Iractures, apparent dips and pressence 01 oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ) .. . . 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data. all fluids recovered and gravity. MEAS.DEPTH TRUE VERT. DEPTH GOR, and time of each phase. CD2-23PB1 Top Alpine D 9353' 7147' Top Alpine C 9375' 7163' CD2-23 Top Alpine D 9468' 7150' Top Alpine C 9514' 7165' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vem Johnson 265-6081 . Signed A.L c.. Ot-€ Title AIDine DrillinQ Team leader Date 9l'2.l.f",- / "- Chip Alvord Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407