**Exhibit99.2**
|            |                                  | RYDER SCOTT COMPANY |                     |       |                      |       | FAX (403)  262-2790 |
|------------|---------------------------------------|---------------------|--------------------------|------------|---------------------------|------------|---------------------|
|       | RYDER SCOTT COMPANY                   |                |                     |       |                      |
|       | 1200, 530 – 8TH AVENUE S.W. |                | CALGARY, ALBERTA T2P 3S8 |       | TELEPHONE (403)  262-2799 |
| ** ** | ** **                            | ** **          | ** **               | ** ** | ** **                | ** ** |                |   |
| ** ** | ** **                            | ** **          | ** **               | ** ** | ** **                | ** ** | ** **          |   |   |
|            |                                       |                     |                          |            |                           |            |                     |  |  |  |  |

January 19, 2007

NorthrockResources Ltd.(A wholly owned subsidiary of Pogo Producing Company)Suite 3500, 700 Second Street S.W.Calgary, AlbertaT2P-2W2
| Attention: |   | Mr. Dave Pearce, President                            |
|------------|--------|-------------------------------------------------------|
|       |   | Mr. Dan Long,  Vice President Corporate Development   |
|       |   | Mr. Dave  Beathard, Senior Vice President Engineering |

 

Gentlemen:

Atyour request, Ryder Scott Company (Ryder Scott) has audited estimates of theremaining proved hydrocarbon liquid and natural gas reserves attributable tocertain properties of Northrock Resources Ltd. (Northrock), as of December 31,2006, as prepared by its engineering and geological staff and based onSecurities and Exchange Commission (SEC) guidelines.  The properties that we reviewed are locatedin the provinces of Alberta, British Columbia, and Saskatchewan, Canada.

Thenet reserves attributable to the properties that we reviewed account for 93.1percent of the total net remaining liquid hydrocarbon reserves 85.7 percent ofthe total net remaining gas reserves. The properties that we reviewed represent 90.9 percent of the totalproved discounted future net income based on the unescalated pricing policy ofthe SEC as taken from reserve and income projections prepared by Northrock asof December 31, 2006.

Theestimated reserves presented in this report are related to hydrocarbonprices.  Northrock has informed us thatin the preparation of their reserve and income projections, as of December 31,2006, they used December 31, 2006 hydrocarbon prices as required by SEC guidelines;however, actual future prices may vary significantly from December 31,2006.  Therefore, volumes of reservesactually recovered and the amounts of income actually received may differsignificantly from the estimated quantities presented in this report.  The estimated net reserves attributable toNorthrock’s interest in properties that we reviewed and the reserves ofproperties that we did not review are summarized as follows:

**SEC CASE**Estimated Net Remaining ReservesAttributable to Certain Properties of**Northrock Resources Ltd.**As of December 31, 2006
| ** **                                                                            | ** ** | ** **    | ** ** | **Proved**        | ** ** | ** **      | ** ** |
|---------------------------------------------------------------------------------------|------------|---------------|------------|-------------------|------------|-----------------|------------|
| ** **                                                                            | ** ** | **Developed** | ** ** | **Total**         | ** ** | ** **      | ** ** |
| ** **                                                                            | ** ** | **Producing** | ** ** | **Non-Producing** | ** ** | **Undeveloped** | ** ** | **Proved** | ** ** |
| ***Net Reserves of PropertiesReviewed by Ryder Scott*** | ** ** | ** **    | ** ** | ** **        | ** ** | ** **      | ** ** | ** ** | ** ** |
| Oil/Condensate — MSTB                                                            |       | 45,462        |       | 2,001             |       | 6,261           |       | 53,724 |   |
| Plant Products — MSTB                                                            |       | 4,965         |       | 140               |       | 1,330           |       | 6,435 |   |
| Gas — MMcf                                                                       | 191,872    |          | 12,913     |              | 67,944     |            | 272,729    |   |

 
| 1200, 530 - 8TH AVENUE, S.W. |   | CALGARY, ALBERTA T2P 3S8    |   | TEL (403) 262-2799 |   | FAX (403) 262-2790 |
|------------------------------|--------|-----------------------------|--------|--------------------|--------|--------------------|
|                         |   |                        |   |               |   |               |
| 621 17TH STREET, SUITE 1550  |   | DENVER, COLORADO 80293-1501 |   | TEL (303) 623-9147 |   | FAX (303) 623-4258 |

 

 

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| ** **                                                                                     | ** ** | **Proved**    | ** ** |
|------------------------------------------------------------------------------------------------|------------|---------------|------------|
| ** **                                                                                     | ** ** | **Developed** | ** ** | ** ** | ** ** | **Total** | ** ** |
| ** **                                                                                     | ** ** | **Producing** | ** ** | **Non-Producing** | ** ** | **Undeveloped** | ** ** | **Proved** | ** ** |
| ***Net Reserves of PropertiesNot Reviewed by Ryder Scott*** | ** ** | ** **    | ** ** | ** ** | ** ** | ** ** | ** ** | ** ** | ** ** |
| Oil/Condensate —  MSTB                                                                    |       | 2,467         |       | 76 |   | 975 |   | 3,518 |   |
| Plant Products —  MSTB                                                                    |       | 803           |       | 4 |   | 133 |   | 940 |   |
| Gas — MMcf                                                                                |       | 31,214        |       | 793 |   | 13,580 |   | 45,587 |   |
|                                                                                           |       |          |       |   |   |   |   |   |   |
| ***Total  Net Reserves***                                                                      | ** ** | ** **    | ** ** | ** ** | ** ** | ** ** | ** ** | ** ** | ** ** |
| Oil/Condensate —  MSTB                                                                    |       | 47,929        |       | 2,077 |   | 7,236 |   | 57,242 |   |
| Plant Products —  MSTB                                                                    |       | 5,768         |       | 144 |   | 1,463 |   | 7,375 |   |
| Gas — MMcf                                                                                |       | 223,086       |       | 13,706 |   | 81,524 |   | 318,316 |   |

 

Liquidhydrocarbons are expressed in standard 42 gallon barrels.  All gas volumes are expressed in millions ofcubic feet (MMcf) at the official temperature and pressure bases of the areasin which the gas reserves are located.

Theproved developed non-producing reserves attributable to the total propertiesare comprised of shut-in and behind pipe reserves.

Theproved reserves, which are attributable to the properties that we reviewed,conform to the definition as set forth in the Securities and Exchange Commission’sRegulation S-X Part 210.4-10 (a) as clarified by subsequent Commission StaffAccounting Bulletins.  The provedreserves are defined as follows:

Provedreserves of crudeoil, condensate, natural gas, and natural gas liquids are estimated quantitiesthat geological and engineering data demonstrate with reasonable certainty tobe recoverable in the future from known reservoirs under existing operatingconditions, i.e., prices and costs as of the date the estimate is made.  Prices include consideration of changes inexisting prices provided only by contractual arrangements, but not onescalation based on future conditions. Reservoirs are considered proved if economic producibility is supportedby either actual production or conclusive formation test.  In certain instances, proved reserves areassigned on the basis of a combination of core analysis and electrical andother type logs which indicate the reservoirs are analogous to reservoirs inthe same field which are producing or have demonstrated the ability to produceon a formation test.  The area of areservoir considered proved includes (1) that portion delineated by drillingand defined by fluid contacts, if any, and (2) the adjoining portions not yetdrilled that can be reasonably judged as economically productive on the basisof available geological and engineering data. In the absence of data on fluid contacts, the lowest known structuraloccurrence of hydrocarbons controls the lower proved limit of the reservoir.  Reserves that can be produced economicallythrough the application of improved recovery techniques are included in theproved classification when these qualifications are met:  (1) successful testing by a pilot project orthe operation of an installed program in the reservoir provides support for theengineering analysis on which the project or program was based, and (2) it isreasonably certain the project will proceed. Improved recovery includes allmethods for supplementing natural reservoir forces and energy, or otherwiseincreasing ultimate recovery from a reservoir, including (1) pressuremaintenance, (2) cycling, and (3) secondary recovery in its originalsense.  Improved recovery also includesthe enhanced recovery methods of thermal, chemical flooding, and the use ofmiscible and immiscible displacement fluids. Proved natural gas reserves are comprised of non-associated, associatedand dissolved gas.  An appropriatereduction in gas reserves has been made for the expected removal of natural gasliquids, for lease and plant fuel, and for the exclusion of non-hydrocarbongases if they occur in significant quantities and are removed prior tosale.  Estimates of proved reserves donot include crude oil, natural gas, or natural gas liquids being held inunderground or surface storage.  Provedreserves are estimates of hydrocarbons to be recovered from a given dateforward.  They may be revised ashydrocarbons are produced and additional data become available.  Proved developed oil and gas reserves arereserves that can be expected to be recovered through

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existing wells with existingequipment and operating methods. Additional oil and gas expected to be obtained through the applicationof fluid injection or other improved recovery techniques for supplementing thenatural forces and mechanisms of primary recovery should be included as “proveddeveloped reserves” only after testing by a pilot project or after theoperation of an installed program has confirmed through production responsethat increased recovery will be achieved.

Proveddeveloped reserves may be subcategorized as producing or non-producing usingthe SPE/WPC Definitions:

*Producing*Reservessub-categorized as producing are expected to be recovered from completionintervals which are open and producing at the time of the estimate.  Improved recovery reserves are consideredproducing only after the improved recovery project is in operation.

*Non-Producing*Reservessub-categorized as non-producing include shut-in and behind pipe reserves.  Shut-in reserves are expected to be recoveredfrom (1) completion intervals which are open at the time of the estimate butwhich have not started producing, (2) wells which were shut-in for marketconditions or pipeline connections, or (3) wells not capable of production formechanical reasons.  Behind pipe reservesare expected to be recovered from zones in existing wells, which will requireadditional completion work or future recompletion prior to the start ofproduction.

Proved undeveloped oil and gas reserves are reserves that are expected to be recoveredfrom new wells on undrilled acreage, or from existing wells where a relativelymajor expenditure is required for recompletion. Reserves on undrilled acreage shall be limited to those drilling unitsoffsetting productive units that are reasonably certain of production whendrilled.  Proved reserves for otherundrilled units can be claimed only where it can be demonstrated withreasonable certainty that there is continuity of production from the existing productiveformation.  Estimates for provedundeveloped reserves are attributable to any acreage for which an applicationof fluid injection or other improved technique is contemplated, only when suchtechniques have been proved effective by actual tests in the area and in thesame reservoir.

***Review Procedure and Opinion***

In our opinion, Northrock’s estimates of future reserves for thereviewed properties were prepared in accordance with generally acceptedprocedures for the estimation of future reserves, and we found no bias in theutilization and analysis of data in estimates for these properties. In someinstances our estimates were higher or lower than Northrock’s; however, ingeneral, we were in reasonable agreement with Northrock’s estimates ofremaining proved reserves for the properties which we reviewed.

Certain technical personnel of Northrock are responsible for thepreparation of reserve estimates on new properties and for the preparation ofrevised estimates, when necessary, on old properties.  These personnel assembled the necessary dataand maintained the data and workpapers in an orderly manner.  We consulted with these technical personneland had access to their workpapers and supporting data in the course of ourreview.

Inperforming our review, we have relied upon data furnished by Northrock withrespect to property interests owned, production and well tests from examinedwells, geological structural and isopachmaps, well logs, core analyses, and pressure measurements.  These data were accepted as authentic andsufficient for determining the reserves unless, during the course of ourexamination, a matter of question came to our attention in which case the datawere not accepted until all questions were satisfactorily resolved.  Our review included such tests and proceduresas we considered necessary under the circumstances to render the conclusionsset forth herein.

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Theoperating costs for the leases and wells were based on the operating expensereports of Northrock and include only those costs directly applicable to theleases or wells. These operating costs have not been verified by Ryder Scott.Northrock has informed us that the operating costs for Northrock operatedproperties do not include general and administrative overhead charges; whereas,administrative overhead charges billed by third parties were included in theoperating costs used for leases and wells which are not operated by Northrock.The current operating and development costs supplied by Northrock were used byRyder Scott without escalation.

***Other Properties***

Other properties, as used herein, are those properties of Northrockwhich we did not review.  The reservesattributable to the other properties account for 6.9 percent of the total netremaining oil/condensate reserves and 14.3 percent of the total net remaining gasreserves.  The same technical personnelof Northrock prepared the reserve estimates for the properties that we reviewedand for the other properties.

***Future Production Rates***

Initial production rates are based on the current producing rates forthose wells now on production. Test data and other related information wereused to estimate the anticipated initial rates for those wells or locationswhich are not currently producing. If no production decline trend has beenestablished, future production rates were held constant, or adjusted for theeffects of curtailment where appropriate, until a decline in ability to producewas anticipated. The future anticipated decline was then applied to depletionof the reserves. If a decline trend has been established, this trend was usedas the basis for estimating future production rates. For reserves not yet onproduction, sales were estimated to commence at an anticipated date of initialproduction which was furnished by Northrock.

The future production rates from wells now on production may be more orless than estimated because of changes in market demand or allowables set byregulatory bodies. Wells or locations which are not currently producing maystart producing earlier or later than anticipated in the estimates of theirfuture production rates.

***Reserve Estimates***

Ingeneral, the reserves for the properties that we reviewed were estimated byperformance methods or the volumetric method or analogy. The reserve estimatesby the performance method utilized extrapolations of various historical data inthose cases where such data were definitive. Reserves were estimated by the volumetric method in those cases wherethere were inadequate historical data to establish a definitive trend or wherethe use of production performance data as a basis for the reserve estimates wasconsidered to be inappropriate and the volumetric data were adequate for areasonable estimate.

Thereserves presented herein, as estimated by Northrock and reviewed by us, areestimates only and should not be construed as being exact quantities.  Moreover, estimates of reserves may increaseor decrease as a result of future operations.

***General***

In general, the reserve estimates for the properties that we reviewedare based on data available through December 2006.  Gas imbalances, if any, were not taken intoaccount in the gas reserve estimates reviewed.

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Neither we nor any of our employees have any interest in the subjectproperties and neither the employment to do this work nor the compensation iscontingent on our estimates of reserves for the properties which were reviewed.

This report was prepared for the exclusive use and sole benefit ofNorthrock Resources Ltd. and may not be put to other use without our priorwritten consent for such use.  The data andwork papers used in the preparation of this report are available forexamination by authorized parties in our offices.  Please contact us if we can be of furtherservice.
|        |   | Yours very truly,                                         |
|--------|--------|-----------------------------------------------------------|
|   |   |                                                      |
|   |   | RYDER SCOTT COMPANY-CANADA                                |
|   |   |                                                      |
|   |   |                                                      |
|   |   |                                                      |
|   |   | Original signed by “Andrew J. Thompson, P.Eng.” |
|   |   |                                                      |
|   |   |                                                      |
|   |   |                                                      |
|   |   | Andrew J. Thompson, P.Eng.                                |
|   |   | Managing Senior Vice President                            |

 

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